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X-WR-CALDESC:Events for SPE WA
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TZID:Australia/Perth
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TZOFFSETFROM:+0800
TZOFFSETTO:+0800
TZNAME:AWST
DTSTART:20190101T000000
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BEGIN:VEVENT
DTSTART;TZID=Australia/Perth:20201119T180000
DTEND;TZID=Australia/Perth:20201119T220000
DTSTAMP:20201117T051548Z
CREATED:20200924T093502Z
LAST-MODIFIED:20201117T051548Z
UID:24315-1605808800-1605823200@www.spe-wa.org
SUMMARY:***SHOWCASE EVENT***SPE APOGCE 2020 CONFERENCE DINNER
DESCRIPTION:TICKET SALES CLOSED \n2020 APOGCE Conference Dinner – Live Event!\nAlthough the APOGCE conference will be held virtually from 17-19 November; the conference dinner for APOGCE will be an in person event. \nThe Western Australian SPE Section invites you to celebrate at the Conference Dinner with stunning views of Perth and Swan River with us at Fraser’s\, Kings Park from 6:00pm for an evening of Networking\, Canapés\, Food Stations and Drinks. \nConference Dinner Guest Speaker: David Low\, WoodMac.\nTopic: “LNG and Future Energy Markets” \nDress: Business Casual \nFlyer:
URL:https://www.spe-wa.org/event/showcase-event-spe-apogce-2020-conference-dinner/
LOCATION:Fraser’s Restaurant\, Kings Park and Botanic Garden\, 60 Fraser Ave\, West Perth\, Western Australia\, 6005\, Australia
ATTACH;FMTTYPE=image/jpeg:https://www.spe-wa.org/wp-content/uploads/2020/09/Dinner-Square.jpg
END:VEVENT
BEGIN:VEVENT
DTSTART;TZID=Australia/Perth:20201117T080000
DTEND;TZID=Australia/Perth:20201119T170000
DTSTAMP:20201015T100512Z
CREATED:20201015T100253Z
LAST-MODIFIED:20201015T100512Z
UID:24437-1605600000-1605805200@www.spe-wa.org
SUMMARY:SPE APOGCE conference preview – A Case Study of Continous Improvement: Successes and Challenges of the Norton Multilateral Development
DESCRIPTION:Paper Number\n:\nSPE-202359-MS\n\n\nPaper Title\n:\nA Case Study of Continous Improvement: Successes and Challenges of the Norton Multilateral Development\n\n\nAuthor Block\n:\nB. Dutta and Q. Cahill\, Woodside; V. Negrini\, C. Jelly and B. Butler\, Halliburton\n\n\n\nAPOGCE Conference 2020 registration: \nhttps://www.spe-events.org/apogce2020/home \nAbstract \nThe recent\, sustained depression in global oil prices has driven a significant reduction in upstream Exploration and Production (E&P) expenditure\, particularly in the capital-intensive offshore environment.  The high costs traditionally associated with E&P development\, specifically in subsea developments\, have driven a requirement for the adoption of technologies that not only increase the efficiency of the well construction process\, but also reduce the total number of wells required\, whilst increasing production rates and reserves. \nBuilding on recent industry experiences with the varying multilateral systems available\, Woodside implemented the use of an alternative innovative multi-lateral system\, which has gone through multiple evolutions and marked improvements in system reliability and installation efficiency compared to Woodside’s previous multilateral experience. The latest evolution of this system has been implemented during the construction of multi-lateral wells for the Greater Enfield Project (GEP). Within GEP\, the Norton over Laverda field development comprises three tri-lateral production wells (namely NOL01\, NOL02 and NOL03).  Norton field is an offset to the Vincent field\, which employed an alternative multi-lateral completion design. On average\, the Norton multi-lateral well operations were executed 15-20% faster than previous comparable Woodside installations. This has been attributed to the application of operational learnings from the previous Vincent multi-lateral Development and the implementation of the new system. These wells were constructed in water depths of > 800 m\, the deepest for such a system globally. Of the three wells\, NOL01 and NOL02 were constructed well under budget\, and ahead of schedule. NOL02 was constructed in a time that benchmarked as the fastest well per 1\,000 m versus basin offsets. NOL03 was completed within budget\, whilst having faced two major NPT (Non-Productive Time) events (ultimately resolved using world first solutions for the given system). This paper will discuss the successes\, challenges experienced\, and lessons learned during the installation of the three Norton tri-laterals. This field is a prime example of how new technology and installation practices of multilateral systems within the operator’s assets of the North-West margin of Australia have improved over time. \n \nRepresentative Layout of a Norton Trilateral
URL:https://www.spe-wa.org/event/spe-apogce-conference-preview-a-case-study-of-continous-improvement-successes-and-challenges-of-the-norton-multilateral-development/
ATTACH;FMTTYPE=image/jpeg:https://www.spe-wa.org/wp-content/uploads/2020/09/APOGCE-2020.jpg
END:VEVENT
BEGIN:VEVENT
DTSTART;TZID=Australia/Perth:20201117T080000
DTEND;TZID=Australia/Perth:20201119T170000
DTSTAMP:20201015T100506Z
CREATED:20201015T100249Z
LAST-MODIFIED:20201015T100506Z
UID:24436-1605600000-1605805200@www.spe-wa.org
SUMMARY:SPE APOGCE conference preview – Wheatstone and Iago Fields Interference Testing: Execution and Interpretation with Ensemble Variance Analysis
DESCRIPTION:Paper Number\n:\nSPE-202390-MS\n\n\nPaper Title\n:\nWheatstone and Iago Fields Interference Testing: Execution and Interpretation with Ensemble Variance Analysis\n\n\nAuthor Block\n:\nM. Flett and P. Connell\, Chevron Australia Pty. Ltd.\n\n\n\nAPOGCE Conference 2020 registration: \nhttps://www.spe-events.org/apogce2020/home \nAbstract \nThe Wheatstone Project is an LNG development located in Western Australia\, incorporating the Chevron Australia operated Wheatstone and Iago fields and third-party gas fields. Production commenced in mid-2017. The start-up of the Wheatstone and Iago fields was a unique opportunity to acquire reservoir surveillance information that was able to provide valuable reservoir insights. A key component of the analysis was the observation of pressure interference between wells from the initial well clean-ups. The design of the well clean-up sequence\, discussed in a previous paper (Flett & Connell\, 2019) was influenced by operational guidelines and the application of Ensemble Variance Analysis to determine an optimised start-up strategy for interference testing with the objective of reducing subsurface uncertainties. \nThe well clean-up sequence was executed safely and achieved the reservoir surveillance and operational objectives of the start-up program. Flexibility in the optimised well clean-up sequence allowed changes to the start-up strategy in response to changing operating conditions\, without impacting the reservoir surveillance objectives. \nHigh quality pressure interference data was acquired\, enabling clear determination of zonal reservoir connectivity within the Wheatstone and Iago reservoirs. Interpretation of pressure interference results with reservoir models\, incorporating Ensemble Variance Analysis led to a change in approach for initial history matching and revision of static and dynamic model development for Wheatstone and Iago fields. \n \nFig. 1—A) Location of Wheatstone and Iago fields\, B) location of development wells and subsea production lines to the Wheatstone Platform
URL:https://www.spe-wa.org/event/spe-apogce-conference-preview-wheatstone-and-iago-fields-interference-testing-execution-and-interpretation-with-ensemble-variance-analysis/
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BEGIN:VEVENT
DTSTART;TZID=Australia/Perth:20201117T080000
DTEND;TZID=Australia/Perth:20201119T170000
DTSTAMP:20201015T100458Z
CREATED:20201015T100246Z
LAST-MODIFIED:20201015T100458Z
UID:24435-1605600000-1605805200@www.spe-wa.org
SUMMARY:SPE APOGCE conference preview – Matrix Water Injection: A Novel Technique
DESCRIPTION:Paper Number\n:\nSPE-202317-MS\n\n\nPaper Title\n:\nMatrix Water Injection: A Novel Technique\n\n\nAuthor Block\n:\nA. Eshtewi\, R. White and S. Campbell\, Woodside Energy Ltd.\n\n\n\nAPOGCE Conference 2020 registration: \nhttps://www.spe-events.org/apogce2020/home \nAbstract \nThe Greater Enfield Project (GEP) is a challenging offshore oil development\, designed to produce from the Laverda Canyon\, Cimatti and Norton over Laverda oil fields. Six water injection wells are required to provide pressure support and sweep oil to three production wells in the Laverda Canyon and Cimatti oil accumulations to improve oil recovery. The GEP injection wells are a critical aspect of water flood design in a complex field\, new to Woodside and with limited global benchmarks. \nThe GEP injection well design is based on a conventional water-based\, sized carbonate reservoir drilling fluid (RDF) combined with a slow release filter cake breaker to deliver direct injection under matrix conditions for the field life. While filter cake chemical breakers have been extensively used in the industry\, their usage is usually combined with a flowback\, which is not available for GEP injection wells due to cost and the inability of some wells to naturally flow during early life. The usage of filter cake breakers to deliver sustainable direct matrix water injection is limited. Industry experience of matrix water injection is often constrained to the first few years of well life\, followed by injection under fracture conditions as result of declining injectivity. This is usually related to inadequate removal of formation damage induced during the construction phase and/or a low-quality injection water. \nGEP injection wells fluid system was designed to limit formation damage and provide uniform filter cake removal to maximise initial injectivity and maintain matrix injection performance for the field life (~10 years). This was achieved using a specific drilling and completion fluids (RDF\, completion fluid and chemical filter cake breaker) combined with a unique clean up and displacement practices. The designed fluid system and operational practices combined with high quality injection water is expected to provide an adequate margin against injectivity decline throughout field life\, with no to minimal well intervention. \nAll GEP injection wells were completed in 2018-2019\, one of which is globally the longest horizontal water injection well completed to date based on the Rushmore data base. Fieldwide injection commenced in July 2019 with favorable results. This paper summarises the key design aspects adopted to deliver successful matrix injection performance\, presents the improvements implemented during offshore execution and provides an insight into the early life injection performance. \n \nFigure 1: Drainage plan for Cimatti (a) Laverda CUS (a) and Laverda CLS (c) shown on a map view \n \nFigure 2: Rushmore data for subsea injection wells \n \nFigure 3: Woodside GEP breaker displacement schematic \n 
URL:https://www.spe-wa.org/event/spe-apogce-conference-preview-matrix-water-injection-a-novel-technique/
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END:VEVENT
BEGIN:VEVENT
DTSTART;TZID=Australia/Perth:20201117T080000
DTEND;TZID=Australia/Perth:20201119T170000
DTSTAMP:20201007T083023Z
CREATED:20201007T083023Z
LAST-MODIFIED:20201007T083023Z
UID:24406-1605600000-1605805200@www.spe-wa.org
SUMMARY:SPE APOGCE conference preview – A Digital Core Laboratory Characterising Oil Water Transition Zones
DESCRIPTION:Paper Number\n:\nSPE-202248-MS\n\n\nPaper Title\n:\nA Digital Core Laboratory Characterising Oil Water Transition Zones\n\n\nAuthor Block\n:\nG.R. Morrison\, Woodside Energy Ltd.\n\n\n\nAPOGCE Conference 2020 registration: \nhttps://www.spe-events.org/apogce2020/home \nAbstract \nA multi-chamber\, finite-difference dynamic model assumed pore-scale reservoir properties (Table 1) and replicated laboratory processes to determine oil-water transition zone characteristics: (1) imbibition residual oil saturation to water flood (distributed as a function of rock properties); (2) imbibition oil-water relative permeability (according to both steady-state and unsteady-state calculations); and\, (3) microscopic oil recovery factor as a function of height above free water level.  A priori\, scaled capillary pressure hysteresis and segregated flow conditions governed pore-scale flow behaviour (initial mobile saturation scaled 0-1) assuming a pipeline network analogue.  Although an oil-water system was modelled the process could be extended to other fluid phases. \nThe dynamic model was divided into five chambers replicating two experiments (Figure 1).  Flow between chambers was regulated by transmissibility multipliers (open/shut).  Replicating a core displacement experiment\, an oil source rock “drained” (flooded) the central core chamber to form the oil-water transition zone; water then imbibed into the core chamber displacing mobile oil into a shallower effluent chamber; capillary pressure hysteresis defined the imbibition residual oil saturation to water flood (Figure 2).  In a second experiment\, the central core chamber was subdivided into zones\, each comprising five model layers\, and the imbibition oil-water relative permeability was determined by flooding the quiesced core chamber situated between high/low-pressure chambers (source/sink).  Both steady-state and unsteady-state relative permeability were determined across the oil-water transition zone. \nThe Digital Core Laboratory (DCL) determined the distribution of imbibition residual oil saturation as a function of: wettability assumption; rock properties; and\, proximity to the free water level.  For a range of wettability assumptions\, imbibition oil-water relative permeability was determined across the transition zone\, on a zonal basis\, from top core chamber (top reservoir) down to the free water level (Figure 3). \nSummary of Results: (1) The imbibition residual oil saturation (ISorw) decreased with depth toward the free water level\, while the drainage irreducible water saturation (Swir) increased with depth; (2) ISorw was found to be strongly influenced by the wettability assumption\, contrasting with the uniformity of Swir; (3) Microscopic oil recovery factor was determined across the transition zone as a function of both proximity to the free water level and the wettability assumption; except for the oil-wet case\, microscopic oil recovery factor increased with depth toward the free water level. \nThe novel approach was the multi-chambered design of the finite difference model forming a Digital Core Laboratory (DCL).   Tuning the model to a Special Core Analysis (SCAL) data set\, with the objective of filling SCAL data gaps\, is expected to be one application. \nTable 1 – Pore-Scale Properties and Processes Mapped to Finite Difference Simulation Parameters \n \n  \n \nFigure 1 – The Multi-Chamber Digital Core Laboratory (DCL) \n  \n \nFigure 2 – Experiment-1: ISorw by Displacement XZ Cross-Section (Red-Green is Oil Saturation\, Blue is Water) \n  \n \nFigure 3 – Experiment-2: Transition Zone Relative Permeability for the Water-Wet Case (USBM WI = +1)
URL:https://www.spe-wa.org/event/spe-apogce-conference-preview-a-digital-core-laboratory-characterising-oil-water-transition-zones/
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END:VEVENT
BEGIN:VEVENT
DTSTART;TZID=Australia/Perth:20201117T080000
DTEND;TZID=Australia/Perth:20201119T170000
DTSTAMP:20201007T083016Z
CREATED:20201007T083016Z
LAST-MODIFIED:20201007T083016Z
UID:24409-1605600000-1605805200@www.spe-wa.org
SUMMARY:SPE APOGCE conference preview – Integrating Reservoir Characterisation\, Diagnostic Fracture Injection Testing\, Hydraulic Fracturing and Post-frac Well Production Data to Define Pressure Dependent Permeability Behavior in Coal
DESCRIPTION:Paper Number\n:\nSPE-202281-MS\n\n\nPaper Title\n:\nIntegrating Reservoir Characterisation\, Diagnostic Fracture Injection Testing\, Hydraulic Fracturing and Post-frac Well Production Data to Define Pressure Dependent Permeability Behavior in Coal\n\n\nAuthor Block\n:\nR.L. Johnson\, Z. You\, A. Ribeiro\, S. Mukherjee\, V.S. Santiago and C. Leonardi\, U. of Queensland\n\n\n\nAPOGCE Conference 2020 registration: \nhttps://www.spe-events.org/apogce2020/home \nAbstract \nDefining pressure dependent permeability (PDP) behaviour in coalbed methane (CBM) or coal seam gas (CSG) reservoirs using reservoir simulation is non-unique based on the uncertainty in coal properties and input parameters.   A diagnostic fracture injection test (DFIT) can be used to investigate bulk permeability at a reservoir level and at lowered net effective stress conditions.  As coal has minimal matrix porosity and under DFIT conditions cleat porosity is fluid saturated with reasonably definable total compressibility values\, the DFIT data can provide insight into PDP parameters.  At pressures above the fissure opening pressure\, pressure dependent leak off (PDL) behaviour increases exponentially with increasing pressure.  Many authors have noted that with decreasing pressure PDP declines exponentially with increasing net effective stress. Thus\, PDP behaviour can be defined by PDL. \nIn this paper\, we show how combined analyses\, using typically collected field data\, can be used to better define and constrain the modelling of PDP.  We illustrate this process based on a well case study that includes the following data: fracture fabric and porosity reasonably defined from image log and areal core studies; DFIT data acquired under initial saturation conditions; hydraulic fracturing data; and longer term production data.  These analyses will be integrated and used to constrain the parameters required to obtain a rate and pressure history-match from the post-frac well production data. \nThis workflow has application in other coal seam gas cases by identifying key variables where hydraulic fracturing performance has been unable to overcome limitations based on pressure or stress dependent behaviours and often accompanied by low reservoir permeability values. While this is purposely targeting areas where only typically collected field data is available\, this workflow can include coal testing data for matrix swelling/shrinkage properties or other production data analysis techniques.
URL:https://www.spe-wa.org/event/spe-apogce-conference-preview-integrating-reservoir-characterisation-diagnostic-fracture-injection-testing-hydraulic-fracturing-and-post-frac-well-production-data-to-define-pressure-depend/
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BEGIN:VEVENT
DTSTART;TZID=Australia/Perth:20201117T080000
DTEND;TZID=Australia/Perth:20201119T170000
DTSTAMP:20201007T083008Z
CREATED:20201007T083008Z
LAST-MODIFIED:20201007T083008Z
UID:24408-1605600000-1605805200@www.spe-wa.org
SUMMARY:SPE APOGCE conference preview – Development of a New Oriented Perforating System for a Challenging Subsurface Environment
DESCRIPTION:Paper Number\n:\nSPE-202391-MS\n\n\nPaper Title\n:\nDevelopment of a New Oriented Perforating System for a Challenging Subsurface Environment\n\n\nAuthor Block\n:\nM. Haigh\, A. Morrison and P. Crabtree\, Chevron; F. Doombosch\, Schlumberger\n\n\n\nAPOGCE Conference 2020 registration: \nhttps://www.spe-events.org/apogce2020/home \nAbstract \nThe Gorgon Stage 2 (GS2) project is a brownfield expansion of the existing Chevron-operated Gorgon Foundation Project (GFP).  GS2 will maintain gas supply to the Gorgon liquified natural gas (LNG) plant by expanding the existing infrastructure with additional subsea wells in the Gorgon and Jansz-Io gas fields.  Low installation risk and high life-cycle reliability were primary objectives of the GS2 well completions due to the high costs associated with subsea installation and intervention.  The Gorgon subsurface environment is hostile with temperatures reaching 165°C\, high concentrations of CO2 and predicted sand production.  The risk to long-term sandface completion reliability is reduced significantly when the perforations are aligned toward the plane of maximum stress.  To achieve the primary well objectives the GS2 project team selected shoot-and-leave\, cased hole\, oriented perforating (CHOP) as the Gorgon completion design. \nChevron partnered with a leading supplier of tubing-conveyed perforating (TCP) equipment to develop a highly reliable\, internally oriented perforating system manufactured from corrosion-resistant alloy (CRA) material\, an industry first.  The development and engineering phase consisted of defining project requirements\, component design\, manufacture of test equipment\, testing\, and system integration tests.  Charge testing was conducted under reservoir conditions to verify that perforating performance met minimum requirements.  Other tests included verification of gun orientation accuracy at Gorgon down-hole temperatures\, a significant undertaking by the TCP supplier. \nTesting and qualification activities were performed at the TCP supplier’s technology center with local Chevron oversight.  Quality assurance (QA) procedures were revised to be more aligned with those typically used for completion equipment\, because in the industry\, TCP equipment has traditionally relied on vendor-specific QA procedures and in-house oversight.  Quality plans were updated to reflect the changes and enable third-party inspection (TPI) during product manufacturing. This paper will share the collaborative efforts of Chevron and the TCP supplier to design and qualify a CRA oriented perforating system and answer important questions such as “How will we build confidence that the TCP guns will orient correctly?” and “Will the perforating charges perform as required under Gorgon down-hole conditions?”
URL:https://www.spe-wa.org/event/spe-apogce-conference-preview-development-of-a-new-oriented-perforating-system-for-a-challenging-subsurface-environment/
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END:VEVENT
BEGIN:VEVENT
DTSTART;TZID=Australia/Perth:20201117T080000
DTEND;TZID=Australia/Perth:20201119T170000
DTSTAMP:20201007T082952Z
CREATED:20201007T082952Z
LAST-MODIFIED:20201007T082952Z
UID:24407-1605600000-1605805200@www.spe-wa.org
SUMMARY:SPE APOGCE conference preview – Unconventional Gas Development in Queensland\, Australia: How Well does it Align with the ‘Golden Rules’ of Gas?
DESCRIPTION:Paper Number\n:\nSPE-202448-MS\n\n\nPaper Title\n:\nUnconventional Gas Development in Queensland\, Australia: How Well does it Align with the ‘Golden Rules’ of Gas?\n\n\nAuthor Block\n:\nK. Witt and A. Garnett\, The U. of Queensland\n\n\n\nAPOGCE Conference 2020 registration: \nhttps://www.spe-events.org/apogce2020/home \nAbstract \nIn 2012\, the International Energy Agency (IEA) released the ‘Golden Rules for a Golden Age of Gas’ – a set of best practice guidelines for unconventional gas development designed to address key environmental and social risks and gain public acceptance of the industry.  This study sought primarily to understand the extent to which the experience of developing a large-scale coal seam gas (CSG) to liquefied natural gas (LNG) industry in Queensland\, Australia was seen to have aligned with the Golden Rules\, and how well the Golden Rules were seen to contribute to public acceptance of the industry. \nAn evaluation tool was developed where the seven Golden Rules and their subclauses were adopted as criteria in a scorecard approach.  We conducted interviews with 32 senior people who had been directly involved in the development of the CSG industry in Queensland\, from local\, state and federal governments\, gas companies\, host communities as well as researchers and consultant ‘experts’. \nThe Queensland experience of unconventional gas development rated reasonably well in relation to the Golden Rules\, with scores of three or higher out of five for four of the seven rule categories. Across all the Golden Rules\, industry performance scored more highly than the effectiveness of the policy/regulatory environment\, highlighting the complex and sometimes conflicted roles of governments in developing a new industry. The rules addressing baseline measurement\, full disclosure and engagement were seen as most important for public acceptance. \nThis study developed a new tool to evaluate perceived social and environmental performance of industry and effectiveness of governance in unconventional gas development applicable across different jurisdictional contexts. This application suggests that baseline measurements\, open disclosure and public engagement should be the focus for building public acceptance. For new gas developments\, these findings highlight the importance of having a robust regulatory environment in place that can coordinate activities and manage cumulative impacts. \n  \n 
URL:https://www.spe-wa.org/event/spe-apogce-conference-preview-unconventional-gas-development-in-queensland-australia-how-well-does-it-align-with-the-golden-rules-of-gas/
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END:VEVENT
BEGIN:VEVENT
DTSTART;TZID=Australia/Perth:20201117T080000
DTEND;TZID=Australia/Perth:20201119T170000
DTSTAMP:20201002T064026Z
CREATED:20201002T064026Z
LAST-MODIFIED:20201002T064026Z
UID:24374-1605600000-1605805200@www.spe-wa.org
SUMMARY:SPE APOGCE conference preview – Use of Big Data and Machine Learning to Optimise Operational Performance and Drill Bit Design
DESCRIPTION:Paper Number\n:\nSPE-202243-MS\n\n\nPaper Title\n:\nUse of Big Data and Machine Learning to Optimise Operational Performance and Drill Bit Design\n\n\nAuthor Block\n:\nS. Cornel\, Baker Hughes Company; G. Vazquez\, Senex Energy Ltd.\n\n\n\nAPOGCE Conference 2020 registration: \nhttps://www.spe-events.org/apogce2020/home \nAbstract \nObjectives / Scope:  \nTime savings and bit longevity is one of the major challenges in Coal Seam Gas unconventional fields Onshore Queensland.  Maximize rate of penetration based on best drilling parameter was the key target to tackle these issues.  The dataset was accumulated from more than 50 bits run.  A supervised machine learning algorithm was used to classify drilling parameters that increase ROP and bit endurance. \nTo achieve this goal\, our focus was on a) optimizing PDC bit design\, drilling hydraulics and b) developing a Drillers Roadmap to ensure optimal parameters were run in the field. \nMethods\, Procedures\, Process:  \nOperator and service company worked closely to selecte two PDC frames and benchmark performance between them. \nA novel approach was then taken to capture the rig sensors data. These steps were as follows: \nCapture big data using sensors integrated on the rig to produce drilling parameters data sets. \nAn algorithm to clean large data sets with the use of Python Pandas libraries was created. \nUsing supervised machine learning and clustering the data to identify which drilling parameters gave the best results. \n\nCreate a Drillers Roadmap identify drilling parameter trends by depth and provide a “sweet spot” based on machine learning for fine tuning operational window.\nProcess the data set using visualisation tools to develop heatmaps vs depth for each of the drilling parameters (WOB\, RPM\, flow rates and Torque) \nResults\, Observations\, Conclusions: \nA formal process for optimizing performance was developed. After 6 wells optimal operating ranges were identified. This process leads the driller to respond to changes in formation and deliver more consistent drilling performance with excellent results. \nROP increased from 80m/hr to 150m/hr\, driven by improved ROP in the lower section of the well \nTime saving of more than 150 hrs over the drilling campaign. \nRefine PDC bit designs based on optimized parameters\, therefore improving bit life through cutter and hydraulic enhancements. \n \nNovel / Additive information:  \nThe innovation of this methodology is to gather drilling information\, cleaning the data with Python using Pandas library thus making this process more efficient. \nAfter the data files were clean and QAQC\, a supervised machine Learning algorithm was used to optimize ROP’s by taking drilling datasets and fine tuning the parameters (WOB\, RPM\, Flow rate) using drilling dynamics (vibration) and MSE models. \nFinally\, innovative visualizations (heatmaps) were produced in order to give a clear insight of the drilling information gathered by the rig sensors to the company men and drillers. \n 
URL:https://www.spe-wa.org/event/spe-apogce-conference-preview-use-of-big-data-and-machine-learning-to-optimise-operational-performance-and-drill-bit-design/
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END:VEVENT
BEGIN:VEVENT
DTSTART;TZID=Australia/Perth:20201117T080000
DTEND;TZID=Australia/Perth:20201119T170000
DTSTAMP:20201002T063343Z
CREATED:20201002T063255Z
LAST-MODIFIED:20201002T063343Z
UID:24372-1605600000-1605805200@www.spe-wa.org
SUMMARY:SPE APOGCE conference preview – Monitoring and Modelling Condensate Banking Effects with the Ichthys Field Production Data
DESCRIPTION:Paper Number\n:\nSPE-202440-MS\n\n\nPaper Title\n:\nMonitoring and Modelling Condensate Banking Effects with the Ichthys Field Production Data\n\n\nAuthor Block\n:\nR. Lizuka\, INPEX Corp.\n\n\n\nAPOGCE Conference 2020 registration: \nhttps://www.spe-events.org/apogce2020/home \nAbstract \nThe Ichthys gas-condensate field is situated in the Browse Basin\, North West Shelf of Australia\, and the field production commenced in July 2018. The Brewster Member\, one of the two reservoirs in the field\, is a liquid-rich sandstone reservoir. One of the major uncertainties is the degree of well productivity impairment\, caused by condensate banking since the dew point pressure is close to the initial reservoir pressure. The objectives of this study are to evaluate the condensate banking impact on well production performance\, and to establish a modelling methodology to consider the condensate banking effect in a full-field simulation model\, based on the field production data. \nPermanent downhole gauges are deployed in the field\, and thus\, downhole pressure can be monitored continuously. We conducted high rate tests for selected wells to monitor well productivity impairment from the condensate banking. This production data was history-matched with a compositional sector model by applying Local Grid Refinement (LGR) and Velocity-Dependent Relative Permeability (VDRP) to account for more accurate physics in the near-well region. With the tuned VDRP model\, skin trends were predicted to increase with various gas rates\, and a skin correlation was established as a function of this gas rate. This correlation is applied to the full-field simulation where LGR and VDRP cannot be applied due to a simulation time constraint. \nThe skin correlation was validated through the history matching\, using the full-field model and was used to predict the future field production performance. We need continuous monitoring of the condensate banking effect\, to further validate the correlation\, because the production data used in this study is less than one-year duration. The correlation is then flexible enough to tune the history matching when necessary. \nWe present the monitoring and modelling of the condensate banking effect with the actual production data. The implementation of the proposed well modelling will help reservoir engineers in considering the condensate banking effect in the field production forecast. \n \nFig. 1—FBHP and gas rate comparisons between black-oil model with skin correlation and compositional model with LGR and VDRP.
URL:https://www.spe-wa.org/event/spe-apogce-conference-preview-monitoring-and-modelling-condensate-banking-effects-with-the-ichthys-field-production-data/
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END:VEVENT
BEGIN:VEVENT
DTSTART;TZID=Australia/Perth:20201117T080000
DTEND;TZID=Australia/Perth:20201119T170000
DTSTAMP:20201002T063109Z
CREATED:20201002T063007Z
LAST-MODIFIED:20201002T063109Z
UID:24369-1605600000-1605805200@www.spe-wa.org
SUMMARY:SPE APOGCE conference preview – A Campaign Of 4D Seismic Monitor Surveys on Australia’s Northwest Shelf
DESCRIPTION:Paper Number\n:\nSPE-202402-MS\n\n\nPaper Title\n:\nA Campaign Of 4D Seismic Monitor Surveys on Australia’s Northwest Shelf\n\n\nAuthor Block\n:\nP. Thomas\, G. Harrowfield\, J. Fitzpatrick and B. Berglin\, Woodside Energy Ltd.\n\n\n\nAPOGCE Conference 2020 registration: \nhttps://www.spe-events.org/apogce2020/home \nAbstract \nWe showcase an innovative campaigning and business-focused approach to reservoir monitoring of multiple fields using 4D (time-lapse) seismic. Benefits obtained in terms of cost\, speed and the quality of insights gained are discussed\, in comparison with a piecemeal approach. Challenges and lessons learned are described\, with a view to this approach becoming more widely adopted and allowing 4D monitoring to be extended to smaller or more marginal fields. \nAn offshore seismic acquisition campaign was planned and successfully executed for a sequence of four 4D monitor surveys for fields located within 250 km of each other on the greater Northwest Shelf of Australia. The four monitors were acquired in H1 2020 comprising (in this order): Pluto Gas Field M2 (second monitor)\, Brunello Gas Field M1 (first monitor)\, Laverda Oil Field M1 and Cimatti Oil Field M1. Encouragement for this programme was derived in part from prior success with Pluto Field M1 (Figure 1). \nCost savings expected from campaigning were realised\, despite three cyclones during operations\, with success largely attributed to detailed pre-survey planning. Also important were the choice of vessel and planning for operational flexibility. The baseline surveys were diverse and required careful planning to achieve repeatability between vintages over each field\, and to optimise the acquisition sequence – minimising time required to reconfigure the streamer spreads between surveys. The Cimatti baseline survey was acquired using a dual-vessel operation; modelling\, combined with now-standard steerable streamers\, showed a single-vessel monitor survey was feasible. These optimisations provided cost savings incremental to the principal economy of sharing vessel mobilisation costs across the whole campaign. \nBoth processing and evaluation (ongoing at the time of writing) are essentially separate per field\, but follow a consistent approach. Processing is carried out by more than one contractor to debottleneck this phase\, with products\, including intermediate quality control (QC) volumes\, delivered as pre-stack depth migrations. An example is shown in Figure 2\, with clear 4D signal identified early in the processing sequence. While full evaluation of the monitor surveys to static and dynamic reservoir model updates will continue beyond 2020\, key initial reservoir insights should emerge within days of processing completion\, with some even earlier from QC volumes. Furthermore\, concurrent 4D evaluations are expected to result in fruitful exchanges of ideas and technologies between fields. \n \nFigure 1: Example from previous 4D monitor evaluation in Pluto Field (M1): relative acoustic impedance difference section\, showing clear hardening (blue) from water ingress into gas reservoir TR27.3. \n \nFigure 2: Section through preliminary 4D processing output from Cimatti M1/baseline surveys\, showing clear 4D signal at the reservoir level. This is a difference volume M1-minus-baseline in 2-way time\, full offset range. 4D signals are expected to become substantially cleaner with ongoing processing.
URL:https://www.spe-wa.org/event/spe-apogce-conference-preview-a-campaign-of-4d-seismic-monitor-surveys-on-australias-northwest-shelf/
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BEGIN:VEVENT
DTSTART;TZID=Australia/Perth:20201117T080000
DTEND;TZID=Australia/Perth:20201119T170000
DTSTAMP:20201002T062628Z
CREATED:20201002T062628Z
LAST-MODIFIED:20201002T062628Z
UID:24368-1605600000-1605805200@www.spe-wa.org
SUMMARY:SPE APOGCE conference preview – Pressure and Rate Transient Analysis via Permanent Downhole Gauges: Application and Challenges at Wheatstone Field
DESCRIPTION:Paper Number\n:\nSPE-202382-MS\n\n\nPaper Title\n:\nPressure and Rate Transient Analysis via Permanent Downhole Gauges: Application and Challenges at Wheatstone Field\n\n\nAuthor Block\n:\nZ. Xia\, A. Haynes and C. Ong\, Chevron Australia Pty. Ltd.\n\n\n\nAPOGCE Conference 2020 registration: \nhttps://www.spe-events.org/apogce2020/home \nAbstract \nThe Wheatstone gas field located in the Northern Carnarvon Basin offshore Western Australia achieved first gas in mid-2017. All seven foundation producers are equipped with permanent downhole gauges (PDHGs) for real-time pressure monitoring. Data from these gauges have been instrumental in understanding dynamic reservoir performance and reducing static uncertainties. The scope of this paper specifically covers the use of pressure and rate transient analyses (PTA and RTA) and the insights that have been gained during the first two years of production. \nSignificant offset distances exist between each PDHG and the reservoir. Corrections were developed to convert the gauge pressure to a reservoir datum\, which primarily account for frictional and gas density changes with varying rates and temperatures within the wellbore. Other physical constraints and effects have been found to be more challenging to overcome\, limiting the quality and interpretability of the pressure transients\, particularly in the middle-time region. These include interference from non-reservoir pressure signals such as liquid fallback during shut-in\, extremely low signal-to-noise ratios in the higher quality formations\, and proximity to boundaries that render a short infinite-acting radial flow (IARF) period that could be masked by wellbore storage. \nAttempts to circumvent these issues have included the use of drawdown transient analysis to complement build-ups. The step-rate test can eliminate liquid fallback entirely\, which allows for better resolution of the IARF period. Rapid choke movements were also trialled to boost the reservoir response in some instances. Interpretations using the drawdown data were further verified in one producer through analysis of the buildup data acquired following a routine downhole safety valve closure\, which benefitted from the trapping of condensed liquid above the closed valve. This provided the cleanest PTA data seen outside of drill stem testing during field appraisal. While successful in the example presented\, no methods have yet been found to reliably increase IARF interpretability in those wells producing from the best quality sands. \nRegarding RTA\, the authors have found very few documented cases in the literature of applying this technique to conventional gas fields. To field-test its applicability in such an environment\, evaluations of drainage volume by producer were performed and found satisfactory when compared with other estimates of gas in-place. It is hoped that a presentation and discussion of this finding will be additive to the reservoir engineering toolkit. \n 
URL:https://www.spe-wa.org/event/spe-apogce-conference-preview-pressure-and-rate-transient-analysis-via-permanent-downhole-gauges-application-and-challenges-at-wheatstone-field/
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BEGIN:VEVENT
DTSTART;TZID=Australia/Perth:20201117T080000
DTEND;TZID=Australia/Perth:20201119T170000
DTSTAMP:20200925T083222Z
CREATED:20200925T083222Z
LAST-MODIFIED:20200925T083222Z
UID:24334-1605600000-1605805200@www.spe-wa.org
SUMMARY:SPE APOGCE conference preview – Development of a Model and Simulation Tool to Predict Hydrate Growth in Flowlines for Gas Hydrate Production
DESCRIPTION:Paper Number\n:\nSPE-202447-MS\n\n\nPaper Title\n:\nDevelopment of a Model and Simulation Tool to Predict Hydrate Growth in Flowlines for Gas Hydrate Production\n\n\nAuthor Block\n:\nS. Sakurai and B.W. Norris\, U. of Western Australia; B. Hoskin and J. Choi\, Oilfield Technologies Pty. Ltd.; T. Nonoue\, Japan Oil\, Gas and Metals National Corp.; E.F. May and Z.M. Aman\, U. of Western Australia\n\n\n\nAPOGCE Conference 2020 registration: \nhttps://www.spe-events.org/apogce2020/home \nAbstract \nNatural gas hydrate has attracted interest as an energy resource capable of meeting the expected growth in global energy demand. Several key issues remain to be tackled to enable commercial production\, one of which is gas hydrate re-association in production lines\, where significant volumes of water are co-produced with free gas. To predict this behavior\, we introduce a model and simulation tool tailored towards hydrate growth in water-dominant turbulent flow. \nWe have produced a model to predict the growth rate of hydrate in water dominant systems\, integrated into an in-house pseudo-steady-state multiphase flow simulator\, named HyFAST. This is a mass transfer limited model where the growth rate is limited by the dissolution of guest gas molecules into the water-continuous phase. It considers the effect of interfacial gas-water bubble surface area\, the degree of turbulence on mixing\, and changes in bulk viscosity caused by hydrate particle formation. The tool is deployed to estimate the hydrate volume formed in production lines during the second offshore methane hydrate production test in Japan. \nInitially\, the model was validated in an experimental study against flowloop data\, where\, at worst\, model predictions showed order of magnitude agreement with experimental growth rates; following this the model was integrated into an overall flow simulation tool used for larger scale predictions. The offshore production test was designed to use two separate lines to produce gas and water\, however\, some gas was entrained into the water production line\, posing a risk of re-association. As such\, our primary focus was on this water production line\, approximately 1 km in length\, rather than the gas production line\, which generally remained outside the hydrate stability region. Our simulation predictions showed that the hydrate volume in the water production line was less than 5 vol%. Coupled with flowloop data which showed that blockages did not occur in similar systems up to 20 vol% hydrate\, this suggests there was not a significant hydrate blockage likelihood in the offshore production test. These initial results suggest that the model may scale well from lab to field\, and that such simulation tools can prove useful in discussing the consequences of hydrate re-association. \nA new model and simulation tool were developed to predict the rate and extent of hydrate growth in water-dominant flow. These were used to predict hydrate formation in both flowloop experiments and actual production lines. The validation results showed that the approach may prove useful in evaluating hydrate blockage propensity in future gas hydrate production.
URL:https://www.spe-wa.org/event/spe-apogce-conference-preview-development-of-a-model-and-simulation-tool-to-predict-hydrate-growth-in-flowlines-for-gas-hydrate-production/
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END:VEVENT
BEGIN:VEVENT
DTSTART;TZID=Australia/Perth:20201117T080000
DTEND;TZID=Australia/Perth:20201119T170000
DTSTAMP:20200925T082955Z
CREATED:20200925T082955Z
LAST-MODIFIED:20200925T082955Z
UID:24333-1605600000-1605805200@www.spe-wa.org
SUMMARY:SPE APOGCE conference preview – Enabling Subsea Well P&A with Modern Vessels
DESCRIPTION:Paper Number\n:\nSPE-202315-MS\n\n\nPaper Title\n:\nEnabling Subsea Well P&A with Modern Vessels\n\n\nAuthor Block\n:\nT.K. Lim\, E. Tellier and M. Campbell\, 2H Offshore\n\n\n\nAPOGCE Conference 2020 registration: \nhttps://www.spe-events.org/apogce2020/home \nAbstract \nAn increasingly common problem faced by subsea well operators is plugging and abandonment (P&A) of wells using modern drilling vessels. This challenge is due to older wellhead and conductor designs which are not fatigue resistant and which have less bending load capacity. Combined with the current trend of using larger and heavier BOP stacks provided by 5th and 6th generation drilling vessels\, this results in large motions and loads transferred to the wellhead\, and hence higher risk of fatigue failure or component capacities being exceeded during P&A. This paper discusses the methodology for assessing the feasibility of performing P&A on wells with modern vessels and evaluates mitigation options available. \nFirstly\, analysis is performed to determine historical fatigue accumulation in the wellhead and conductor system from drilling and completion operations. Historical fatigue accumulation can be refined by incorporating details from the operational history including vessel heading\, metocean conditions\, and riser configuration. Fatigue accumulation from planned P&A operations with modern day drilling rigs is then assessed to determine if there is sufficient remaining fatigue margin for the planned P&A operations. If required\, mitigation measures such as optimizing riser tension and vessel heading\, reducing BOP stack size\, calibrating analysis models using monitoring data and using a BOP tether system are evaluated. Strength assessment for P&A operations is also performed to determine vessel station keeping requirements. Examples from a number of case studies of recent subsea well P&A in Australia are presented. \nThe effectiveness of different fatigue mitigation measures are compared. Findings presented in the paper allow operators to efficiently evaluate and plan safe P&A operations on older wells with modern drilling vessels. \n 
URL:https://www.spe-wa.org/event/spe-apogce-conference-preview-enabling-subsea-well-pa-with-modern-vessels/
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END:VEVENT
BEGIN:VEVENT
DTSTART;TZID=Australia/Perth:20201117T080000
DTEND;TZID=Australia/Perth:20201119T170000
DTSTAMP:20200925T082801Z
CREATED:20200925T082801Z
LAST-MODIFIED:20200925T082801Z
UID:24332-1605600000-1605805200@www.spe-wa.org
SUMMARY:SPE APOGCE conference preview – Gorgon Produced Water Treatment and Disposal: Commissioning and Operating a Vital Part of LNG Production
DESCRIPTION:Paper Number\n:\nSPE-202401-MS\n\n\nPaper Title\n:\nGorgon Produced Water Treatment and Disposal: Commissioning and Operating a Vital Part of LNG Production\n\n\nAuthor Block\n:\nD. O’Reilly\, B. Yee and A. House\, Chevron Australia Pty. Ltd.\n\n\n\nAPOGCE Conference 2020 registration: \nhttps://www.spe-events.org/apogce2020/home \nAbstract \nThe Gorgon gas plant produces 15.6MTPA Liquified Natural Gas (LNG) from the Gorgon and Jansz-Io subsea gas fields. First LNG production commenced on the Barrow Island\, Australia facility in 2016. One of the first systems commissioned was the wastewater treatment\, collection and disposal system\, a critical support utility for production operations. The Produced Water Disposal (PWD) facility is unique on Barrow Island due the location’s national nature reserve status\, and all treated waste must be disposed downhole. The objective of this paper is to review key lessons from design\, startup and steady state operations. Perspectives will be given on facility/well management and production operations of PWD at the Gorgon plant. \nWastewater on Barrow Island is generated from several sources: Condensed water originating from hydrocarbon gas (separated at gas dehydration and MEG regeneration facilities)\, drainage and runoff water from the plant\, treated sewage effluent and other ad hoc liquid waste. These sources are collected and treated before the final product is pumped into two available onshore disposal wells. One of the challenges initially faced was that the disposal water quality did not meet the design specification required to maintain well performance. This problem reduced as the plant reached steady state operations and the team gained a better understanding of well performance over time. Other current challenges include hydrocarbon carryover and water polishing\, and Engineering and Operations work together closely to ensure reliable water disposal and hence LNG production. \nThis case study will explore the success and lessons learnt in Gorgon PWD through a summary of field data\, facility descriptions and experiences. An overview of the design will be given along with photographs of key components. The required design performance will be compared against actual operating data. In the new energy landscape\, the Upstream Operators’ social license to operate centers around our environmental performance. In our work we demonstrate that it is possible to treat and dispose of waste liquids responsibly while generating cashflow through LNG production. \n 
URL:https://www.spe-wa.org/event/spe-apogce-conference-preview-gorgon-produced-water-treatment-and-disposal-commissioning-and-operating-a-vital-part-of-lng-production/
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END:VEVENT
BEGIN:VEVENT
DTSTART;TZID=Australia/Perth:20201117T080000
DTEND;TZID=Australia/Perth:20201119T170000
DTSTAMP:20200925T082526Z
CREATED:20200925T082526Z
LAST-MODIFIED:20200925T082526Z
UID:24331-1605600000-1605805200@www.spe-wa.org
SUMMARY:SPE APOGCE conference preview – Probabilistic Assessment of Pressure Depletion and Inflation and its Impact on the Drilling Sequence for the Sangomar Field\, Senegal
DESCRIPTION:Paper Number\n:\nSPE-202360-MS\n\n\nPaper Title\n:\nProbabilistic Assessment of Pressure Depletion and Inflation and its Impact on the Drilling Sequence for the Sangomar Field\, Senegal\n\n\nAuthor Block\n:\nL. Gavin and P. Jagtenberg\, Woodside Energy\n\n\n\nAPOGCE Conference 2020 registration: \nhttps://www.spe-events.org/apogce2020/home \nAbstract \nThe Sangomar Feld Development\, located offshore Senegal\, will consist of 23 wells targeting stacked reservoirs\, with horizontal lengths up to 1500m. Due to the long drilling campaign wells are likely to be drilled after first production targeted for 2023. At the time of drilling reservoir pressure in these wells will be affected by nearby producers and injectors\, which will reduce the mud window in the reservoirs\, affecting the drillability. \nVulnerable wells were identified by a deterministic borehole stability assessment based on mud weight windows and a probabilistic well-by-well analysis of reservoir pressure at the time of drilling. The estimated mud weight windows were unique to each well and were a function of completion type\, overburden thickness and well azimuth. Capturing all reservoir uncertainties resulted in 216 models which were reduced to a more manageable 20 for simulation using a distance-based K-medoid algorithm. Maps of maximum depletion and inflation were generated for each of the medoids. \nThe importance of probabilistically assessing reservoir pressures is demonstrated in the context of drill sequence\, we show results can vary significantly depending on the reservoir models used. Potential magnitudes of depletion and inflation in some scenarios were significantly greater than initially anticipated. The combination of borehole stability assessment and probabilistic well-by-well analysis of reservoir pressure allowed clear identification of wells at increased risk of borehole stability problems caused by injection or depletion. Subsequently\, the drilling sequence was updated to mitigate borehole stability risks by executing potential problem wells prior to first production and prioritising key water injectors\, enabling management of post-production depletion while continuing to meet the other objectives such as maximising early production potential. \nThis paper outlines an innovative workflow which captures the range of subsurface uncertainties to define probabilistic impact of depletion and injection on borehole stability. Within the literature we have not seen any examples of depletion and inflation being assessed probabilistically on multiple models or using a map-based format. Depletion and inflation are also often discussed in the context of producing fields\, not during the first phase of drilling\, as is the case for the Sangomar Field.
URL:https://www.spe-wa.org/event/spe-apogce-conference-preview-probabilistic-assessment-of-pressure-depletion-and-inflation-and-its-impact-on-the-drilling-sequence-for-the-sangomar-field-senegal/
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END:VEVENT
BEGIN:VEVENT
DTSTART;TZID=Australia/Perth:20201117T080000
DTEND;TZID=Australia/Perth:20201119T170000
DTSTAMP:20200918T061936Z
CREATED:20200918T061814Z
LAST-MODIFIED:20200918T061936Z
UID:24267-1605600000-1605805200@www.spe-wa.org
SUMMARY:SPE APOGCE conference preview – Automated Pattern Recognition as a Temporary Replacement for Downhole Pressure Gauges
DESCRIPTION:Paper Number\n:\nSPE-202387-MS\n\n\nPaper Title\n:\nAutomated Pattern Recognition as a Temporary Replacement for Downhole Pressure Gauges\n\n\nAuthor Block\n:\nJ. Lyall\, A. Watt and C. Murphy\, Woodside Energy Ltd.\n\n\n\nAPOGCE Conference 2020 registration: \nhttps://www.spe-events.org/apogce2020/home \nAbstract \nAutomated pattern recognition with basic\, high-level coding can be readily applied to petroleum production surveillance to reduce the impact of equipment failure. Machine learning is an application of regression techniques which range in complexity from simple linear regressions to convolutional neural networks. This paper outlines a machine learning based solution that was developed in response to downhole gauge failure\, a common petroleum engineering problem. \nA temporary proxy for downhole pressure measurements was developed after gauge failure on an offshore gas production well. A solution was found in the machine learning space by applying multivariate linear regression to represent relationships within the production system. The workflow presented is based on Python code using the open source SKLearn library. The paper provides Python code example which readers can adapt to the context of their own specific requirements. \nThe method uses available production data (known conditions of pressure and temperature from the wellhead and further downstream\, choke settings and well total mass flow rates) to predict an unknown downhole pressure. The failure of a downhole gauge was simulated by removing the downhole data from the dataset at a certain point in time. The machine learning model was trained using 19 months of well production data. The nine months that follow was then entered under gauge failure conditions (with downhole data removed)\, to predict downhole pressure from other production data. The result was a downhole pressure prediction within 0.2% (40 kPa) of the actual gauge measurement up to nine months after the simulated gauge failure. \nThe prediction was compared to downhole pressure estimations that were calculated with the operator’s calibrated physical well model using the Mukherjee-Brill correlation. The machine learning model outperformed the conventional physical correlation over the test period. The model was validated as an adequate short-term replacement for downhole pressure measurement for an offshore gas well. The solution delayed disruption to the management of reserves\, enabled the continuation of production forecasting and postponed subsea intervention. \nThis paper also provides a foundation for assisted trend analysis\, in which a gauge that is identified as drifting from the long-term trend can aid in the detection of physical changes such as water breakthrough.
URL:https://www.spe-wa.org/event/spe-apogce-conference-preview-automated-pattern-recognition-as-a-temporary-replacement-for-downhole-pressure-gauges/
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END:VEVENT
BEGIN:VEVENT
DTSTART;TZID=Australia/Perth:20201117T080000
DTEND;TZID=Australia/Perth:20201119T170000
DTSTAMP:20200918T062110Z
CREATED:20200918T061609Z
LAST-MODIFIED:20200918T062110Z
UID:24266-1605600000-1605805200@www.spe-wa.org
SUMMARY:SPE APOGCE conference preview – Operational Considerations During Gas-Condensate Well Start-up
DESCRIPTION:Paper Number\n:\nSPE-202249-MS\n\n\nPaper Title\n:\nOperational Considerations During Gas-Condensate Well Start-up\n\n\nAuthor Block\n:\nC. Chan and J. Zhang\, Wood\n\n\n\nAPOGCE Conference 2020 registration: \nhttps://www.spe-events.org/apogce2020/home \nAbstract \nGas hydrates are ice-like crystals formed by gas and free water molecules under low temperature and high-pressure condition of the subsea environment. Avoiding the formation of hydrate plugs is one of the critical tasks that continuously challenges oil and gas operators\, especially as oil and gas operations move into deepwater reserves and longer subsea tiebacks are often required to transport hydrocarbons from the wellhead to the production facilities. \nCommon mitigation measures for hydrate formation and plugging in subsea gas-condensate flowlines include the traditional control methods of injecting hydrate inhibitor that assure the operational conditions are outside the hydrate risk region. However\, inhibitor injection rates are typically designed based on the worst operating conditions (i.e.\, maximum pressure and minimum temperature) with significant safety margin. During transient operation such as well start-up\, the risk of hydrate formation is higher compared to normal operation and requires significant volume of hydrate inhibitor. As the water cut increases at the late life of the field production\, the conventional method of injecting thermodynamic hydrate inhibitor faces technical\, economic and operational limitations. Low dosage hydrate inhibitor on the other hand\, do not offer permanent solutions to hydrate inhibition. \nThis paper goes through an overview of some of the key operational factors i.e.\, existing field data and field practice to be considered during the design phase of gas-condensate subsea tiebacks. For the design of a subsea tieback where field data of the existing facilities are available\, this presents an opportunity to refine the hydrate inhibitor dosing rate through benchmarking with historical data. Two case studies that integrate field experience are presented to illustrate the benefits of applying these operational factors in refining the hydrate inhibition injection during subsea tieback gas-condensate field start-up. \nThe first case study shows how the shutdown and start-up scenarios typically considered for design are too conservative. Aqueous arrival and fluid temperature downstream of choke was benchmarked\, which helped narrow down the shutdown and start-up scenarios to be assessed (Figure 1). As the scenarios considered are now less onerous\, MEG injection rate during well start-up can be reduced by 33% and this increases economic feasibility of the offshore gas-condensate field development.
URL:https://www.spe-wa.org/event/spe-apogce-conference-preview-operational-considerations-during-gas-condensate-well-start-up/
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END:VEVENT
BEGIN:VEVENT
DTSTART;TZID=Australia/Perth:20201117T080000
DTEND;TZID=Australia/Perth:20201119T170000
DTSTAMP:20200918T061432Z
CREATED:20200918T061355Z
LAST-MODIFIED:20200918T061432Z
UID:24264-1605600000-1605805200@www.spe-wa.org
SUMMARY:SPE APOGCE conference preview – A New Field Benchmarking Process and Insights for Australia’s Offshore Gas Developments
DESCRIPTION:Paper Number\n:\nSPE-202226-MS\n\n\nPaper Title\n:\nA New Field Benchmarking Process and Insights for Australia’s Offshore Gas Developments\n\n\nAuthor Block\n:\nP. Tingate\, J. Monro\, E. Pereira and M. Webb\, National Offshore Petroleum Titles Administrator; R. Hamp\, PRM Pty. Ltd.\n\n\n\nAPOGCE Conference 2020 registration: \nhttps://www.spe-events.org/apogce2020/home \nAbstract \nAustralia’s National Offshore Petroleum Titles Administrator (‘NOPTA’) has completed a project to gain more detailed insights from field development and performance monitoring of Australian offshore gas developments in Commonwealth waters (excluding state and Northern Territory coastal waters). These insights help identify benchmarks for optimum long-term recovery and aspects of good oilfield practice when evaluating existing and future gas field developments. The methodology applied\, high-level metrics\, example analysis plots and key insights are discussed. \nA new confidential in-house Field Benchmarking Database (‘Database’) has been built\, collating a large subset of Australian offshore gas field data acquired by NOPTA from titleholders. The key datasets (Figure 1) include field and reservoir properties\, facilities data\, development timelines and development costs. The Database also references reserves information\, production data and estimated ultimate recovery\, thereby allowing for quantified analysis and assessment of offshore gas fields in Commonwealth waters within a variety of subsurface\, development\, operational and commercial contexts. \n \nData set correlations based on actual and planned long-term gas field performance\, capital investment\, and resource recovery are utilised to create a range of benchmarking plots focussed on production efficiency\, recovery efficiency\, schedule efficiency and cost efficiency. A number of key insights from these metrics are presented. \nThe approach presented lends itself to all petroleum resources within Australian waters. However\, this exercise has focussed on gas fields where there are a large number of data (e.g. within each basin\, reservoir age\, etc.) and where there is a diversity of field performance experience. \nConsistent with NOPTA’s role and resource management objectives\, the new Database and workflows enable efficient analysis of past\, present and future field developments. This facilitates the ongoing assessment of developed and undeveloped field performance with regard to recovery\, production\, capital and schedule efficiencies. Thus\, improvement opportunities can be identified. \nAlthough the Database which underpins these insights represents a high-level view of the field and project performance data\, it demonstrates the key influencing effects of reservoir quality\, resource size and field location. The outcomes of benchmarking are also used to support more performance improvement focussed discussion between the NOPTA and titleholders. Additionally\, the benefits of improved recovery initiatives as well as late life investments can be evaluated. \nExisting commercial databases and benchmarks do not have a comprehensive dataset of regional analogues specific to Australian offshore petroleum resources\, particularly for gas field developments. The derived insights are practically useful and valuable for both titleholders and NOPTA\, with the shared objective of delivering continuous improvement in optimum long-term recovery and good oilfield practice.
URL:https://www.spe-wa.org/event/spe-apogce-conference-preview-a-new-field-benchmarking-process-and-insights-for-australias-offshore-gas-developments/
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END:VEVENT
BEGIN:VEVENT
DTSTART;TZID=Australia/Perth:20201117T080000
DTEND;TZID=Australia/Perth:20201119T170000
DTSTAMP:20200918T060948Z
CREATED:20200918T060846Z
LAST-MODIFIED:20200918T060948Z
UID:24262-1605600000-1605805200@www.spe-wa.org
SUMMARY:SPE APOGCE conference preview – Wheatstone: What we have Learnt in Early Production Life
DESCRIPTION:Paper Number\n:\nSPE-202246-MS\n\n\nPaper Title\n:\nWheatstone: What we have Learnt in Early Production Life\n\n\nAuthor Block\n:\nJ. Pescod\, P. Connell\, Z. Xia\, J. Herriman\, A. Strong and A. House\, Chevron Australia Pty. Ltd.\n\n\n\nAPOGCE Conference 2020 registration: \nhttps://www.spe-events.org/apogce2020/home \nAbstract \nWheatstone and Iago commenced production in June 2017.  Its foundation subsea system includes nine Wheatstone and Iago development wells tied back to a central Wheatstone Platform (WP) for processing. Hydrocarbons then flow via an export pipeline to an onshore processing facility that includes 2 x liquefied-natural-gas (LNG) trains and a domestic gas (Domgas) facility. \nData from subsea wells\, manifolds and flowlines\, along with data from WP and the Wheatstone LNG Plant are continually monitored to ensure wells and equipment are operating within allowable limits.  Observed and expected performance are routinely compared to recognise any unexpected performance for further investigation. \nThis paper will highlight some of the key learnings in well and reservoir surveillance analysis and optimisation (SA&O) that have been developed using the data from early production. Production strategies will be discussed\, along with factors that need to be considered when developing a preferred strategy through operational and production challenges. Insights will be provided in how to assess the performance and reliability of equipment\, including pressure and temperature gauges\, flowmeters and chokes. Discussion will also include reservoir surveillance and analysis techniques used\, what information is yielded from the different analyses and what surveillance and analysis techniques and tools have worked best. \nPractical examples will be shared that includes tubing and inflow trends\, drawdown analysis\, equipment performance\, and the operational and production challenges of trunkline pressure management.
URL:https://www.spe-wa.org/event/spe-apogce-conference-preview-wheatstone-what-we-have-learnt-in-early-production-life/
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END:VEVENT
BEGIN:VEVENT
DTSTART;TZID=Australia/Perth:20201117T080000
DTEND;TZID=Australia/Perth:20201119T170000
DTSTAMP:20200911T084037Z
CREATED:20200911T083714Z
LAST-MODIFIED:20200911T084037Z
UID:24216-1605600000-1605805200@www.spe-wa.org
SUMMARY:SPE APOGCE conference preview – An Integrated Approach for Tackling Horizontal Drilling Challenges in Eromanga Basin to Maximise Production Benefits
DESCRIPTION:Paper Number\n:\nSPE-202356-MS\n\n\nPaper Title\n:\nAn Integrated Approach for Tackling and Resolving Horizontal Drilling Challenges in Eromanga Basin to Maximise Production Benefits\n\n\nAuthor Block\n:\nS. McDermott\, Beach Energy; H. Wang\, X. Jiang and Y. Liu\, Schlumberger\n\n\n\nAPOGCE Conference 2020 registration: \nhttps://www.spe-events.org/apogce2020/home \nAbstract \nEromanga Basin in central Australia was deposited from early Jurassic to late Cretaceous and has witnessed commercial discoveries in different formation units throughout the basin’s spatial distribution. Lately\, operators have shifted from vertical to horizontal wells to enhance production outcomes. However\, there are still many challenges for achieving and enhancing these benefits with horizontal drilling. These include navigating an undulating reservoir structure whilst staying in the target zone and maintaining appropriate vertical standoff from oil water contact (OWC) to avoid early water breakthrough. \nIn this paper\, the author summarizes the experiences and approaches made in tackling and resolving these challenges\, by elaborating on the new methods applied during the recent horizontal drilling campaign. These include new drilling technologies\, such as the latest rotary steerable systems and new logging-while-drilling technologies\, such as the multilayer bed boundary detection services. The methodology of using this data both while-drilling and post-drilling for critical decision making on both geosteering and completion strategies\, is also addressed. The author illustrates an integrated approach that was adopted by incorporating new data into the reservoir model for the purpose of referencing and planning future wells. \nCase studies from two of the recent wells are discussed in detail to illustrate the operational workflows and the integrated approach. Landing and geosteering practices are examined separately to demonstrate how to achieve best results and avoid both identified and potential pitfalls. The overall drilling and production performance of the recent ten wells are summarized\, as are the results of applying these methods. Finally\, the author reveals the new insights that the post-job data integration brought for the field. \nThis new approach has allowed the operator to drill an increased number of wells than originally planned in the same timeframe. This approach has also allowed for longer wells to be drilled. By comparing the production benefits with the cost of drilling\, the author shows the viability of these methods in resolving the challenges of horizontal drilling in this region. \n \nFig 1 Post-drilling data integration and visualization in 3D for the horizontal wells drilled in this campaign using this approach.
URL:https://www.spe-wa.org/event/spe-apogce-conference-preview-an-integrated-approach-for-tackling-horizontal-drilling-challenges-in-eromanga-basin-to-maximise-production-benefits/
ATTACH;FMTTYPE=image/jpeg:https://www.spe-wa.org/wp-content/uploads/2020/09/APOGCE-2020.jpg
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BEGIN:VEVENT
DTSTART;TZID=Australia/Perth:20201117T080000
DTEND;TZID=Australia/Perth:20201119T170000
DTSTAMP:20200911T083329Z
CREATED:20200911T083329Z
LAST-MODIFIED:20200911T083329Z
UID:24215-1605600000-1605805200@www.spe-wa.org
SUMMARY:SPE APOGCE conference preview – Validation of a Novel Meg Sensor Employing a Pilot-scale Subsea Jumper
DESCRIPTION:Paper Number\n:\nSPE-202375-MS\n\n\nPaper Title\n:\nValidation of a Novel MEG Sensor Employing a Pilot-scale Subsea Jumper\n\n\nAuthor Block\n:\nA. Kumar\, The U. of Western Australia; M. Di Lorenzo\, CSIRO Energy; B.W. Norris\, The U. of Western Australia; A. Lupeau and H. Solheim\, OneSubsea; Z.M. Aman\, The U. of Western Australia\n\n\n\nAPOGCE Conference 2020 registration: \nhttps://www.spe-events.org/apogce2020/home \nAbstract \n  \nOnline pipeline management systems provide real-time and look-ahead functionality for production networks. However\, they are limited by a dearth of data to inform their predictions. This represents a barrier to a true\, high-fidelity ‘digital twin’ where greater integration with new sensor technologies is needed to bound model predictions and improve their reliability. In this work\, we present a novel MEG (Mono-ethylene glycol) sensing system from OneSubsea\, the AquaWatcher v2.0\, and validate it in our newly-constructed HyJump flowloop. The HyJump flowloop has a unique subsea jumper-like geometry\, with three low points and two high points and is equipped with a MEG sensor – mounted on the second low point. The sensor features an open-ended microwave frequency probe mounted flush to the pipe wall which measures the apparent permittivity of the liquid phases in the vicinity of the probe tip. It can determine the MEG concentration or water salinity by processing the measured permittivity\, and has further shown that it may be able to detect hydrate deposition. Experimental work was performed to test the performance of this novel equipment while enabling a more accurate calculation of the overall mass balance in the flowloop. An experimental campaign was conducted where\, in each measurement\, the jumper low points were loaded with aqueous solutions of MEG at mass fractions between 10 and 30 wt%. The entire loop was then pressurized with Perth city natural gas to 1200 psi. The pipe wall temperature was controlled with a cooling jacket in the range of 25.2 °F to 35.6 °F. These conditions simulate transient shut-down and restart operations with a high-risk of hydrate formation. Results illustrate that the MEG content readings measured by the sensor were consistently accurate within a 5% relative deviation with respect to the nominal values. Further\, hydrate restrictions were assessed in their severity through differential pressure measurements\, where it was observed that the measured MEG content oscillates significantly during hydrate sloughing-type events. The HyJump flowloop facility offers a unique testbed for new subsea sensors\, enabling performance evaluations with internal fluids at subsea conditions. The deployment of these novel sensors in the field will both improve the performance of integrated pipeline management solutions and assist operators in optimizing MEG injection dosages to enable higher fidelity hydrate management in subsea pipelines. \n 
URL:https://www.spe-wa.org/event/spe-apogce-conference-preview-validation-of-a-novel-meg-sensor-employing-a-pilot-scale-subsea-jumper/
ATTACH;FMTTYPE=image/jpeg:https://www.spe-wa.org/wp-content/uploads/2020/09/APOGCE-2020.jpg
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BEGIN:VEVENT
DTSTART;TZID=Australia/Perth:20201117T080000
DTEND;TZID=Australia/Perth:20201119T170000
DTSTAMP:20200911T083428Z
CREATED:20200911T083009Z
LAST-MODIFIED:20200911T083428Z
UID:24212-1605600000-1605805200@www.spe-wa.org
SUMMARY:SPE APOGCE conference preview – Improved Characterisation of Emulsions Associated with Inflow Control Devices
DESCRIPTION:Paper Number\n:\nSPE-202366-MS\n\n\nPaper Title\n:\nImproved Characterisation of Emulsions Associated with Inflow Control Devices\n\n\nAuthor Block\n:\nM.A. Jackson\, U. of Western Australia; B. Hoskins\, Oilfield Technologies Pty. Ltd.; N. Ling and M. Johns\, U. of Western Australia; R. Gudimetla and C. Conitsiotis\, BHP Petroleum\n\n\n\nAPOGCE Conference 2020 registration: \nhttps://www.spe-events.org/apogce2020/home \nAbstract \nWater-oil emulsion formation is commonly observed at wellhead chokes and topsides control valves\, with the impact mitigated by chemical injection. The presence of emulsions downhole in Pyrenees wells was inferred from their significant production rate impact and confirmed by the uplift observed from downhole chemical injection.  The Pyrenees fields are located in the Exmouth sub-basin offshore Western Australia. Through analogy between individual Inflow Control Device (ICD) orifice elements and wellhead chokes\, ICDs were suspected as the source.  This paper describes experimental confirmation of emulsion formation by orifice type inflow control devices in Pyrenees field horizontal well completions and proceeds to characterise the emulsions formed.  A purpose built flow rig combined Pyrenees crude oil and produced water under low shear\, simulating reservoir flow conditions\, before flowing through an orifice element at rates equal to peak and mid-life production. \n \nICD Flow Rig General Arrangement (Oilfield Technologies) \nWith liquid flow rate held constant\, water cut was increased in 10% steps from 0 to 100% water content.  At low water cuts virtually all the water was incorporated into the emulsion phase.  At higher water cuts the proportion of water incorporated in the emulsion reduced resulting in free water and emulsion fractions (refer Figure). \nLaboratory emulsions are generally created by techniques including bottle tests and laboratory blenders with agitation applied until a uniform emulsion results as opposed to the limited residence time of the oil and water in the ICD orifice. \n \nA key component of the experimental system is a benchtop Nuclear Magnetic Resonance spectrometer equipped for non-invasive Pulsed Field Gradient measurement of the Droplet Size Distribution of the emulsions formed.  The NMR instrument also measured the proportion of water incorporated in the emulsion phase through hydrogen nucleus (1H) spectrometry.  Droplet size distribution is a fundamental fluid property that significantly impacts emulsion rheology.  The heavy end component of the crude oil was characterised by a novel Enhanced Saturate Aromatic Resin and Asphaltene analysis procedure to facilitate benchmarking of Pyrenees with emulsion formation tendencies of other producing assets.  This quantitative demonstration of emulsion formation by orifice type ICDs at near reservoir conditions is novel\, as is observation of partial emulsification\, and represents initial steps towards generalisation of models for emulsion formation and their transport properties. \n 
URL:https://www.spe-wa.org/event/spe-apogce-conference-preview-improved-characterisation-of-emulsions-associated-with-inflow-control-devices/
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BEGIN:VEVENT
DTSTART;TZID=Australia/Perth:20201117T080000
DTEND;TZID=Australia/Perth:20201119T170000
DTSTAMP:20200911T082605Z
CREATED:20200911T081108Z
LAST-MODIFIED:20200911T082605Z
UID:24209-1605600000-1605805200@www.spe-wa.org
SUMMARY:SPE APOGCE conference preview - Regulatory Challenges and Opportunities for Optimising Petroleum Resource Stewardship in Offshore Australia
DESCRIPTION:Paper Number\n:\nSPE-202268-MS\n\n\nPaper Title\n:\nRegulatory Challenges and Opportunities for Optimising Petroleum Resource Stewardship in Offshore Australia\n\n\nAuthor Block\n:\nJ. Miranda\, National Offshore Petroleum Tiles Administrator; R. Hamp\, PRM Pty. Ltd.; E. Cocodia and N. Filbay\, National Offshore Petroleum Tiles Administrator\n\n\n\n\nAPOGCE Conference 2020 registration: \nhttps://www.spe-events.org/apogce2020/home \nAbstract \nThe challenges and insights presented in this paper provide a unique case study of Australia’s evolving offshore petroleum industry from a regulatory lens. It documents how a regulating agency’s unique perspective can identify opportunities to optimise recovery\, contribute towards improvements in good oil practice and ultimately adapt to the changing requirements of industry. \nThis paper sets out the regulatory landscape\, as well as the challenges that exist in managing an innovative\, adaptive and evolving offshore petroleum industry. The nature of petroleum development activities in offshore waters have matured significantly in the last 50 years (Table 1)\, contributing to Australia becoming the world biggest LNG exporter for periods during 2018 and 2019. Consequently\, it has been argued that due to this shift towards more mature production\, the objectives for effective resource management and stewardship should be reconsidered. For example\, as offshore basins mature (i.e. discoveries are made\, infrastructure is built\, and production ramps up) different drivers for development will evolve which will impact resource stewardship considerations. \nThis challenges regulators to be increasingly responsive\, adaptive\, continuously improve practices and be well-informed regarding global trends\, such as those affecting mature provinces. Opportunities to exchange ideas\, collaborate and incorporate key learnings from other offshore regulatory regimes are considered key enablers towards achieving these goals. \nAustralia’s mature petroleum areas are impacted by long distances\, (relatively) low infrastructure densities and greater water depths; whilst increasingly challenged to integrate smaller\, more complex and economically marginal resources. Emerging/recently established production areas are also affected by a changing infrastructure landscape with multiple potential development pathways. In contrast to traditional “title-by-title” approaches (particularly with respect to the use of existing infrastructure)\, effective resource stewardship requires an increased level of consideration for optimising “area” or “regional” development opportunities. A more responsive and adaptive approach\, which fosters collaboration and effective dialogue between the regulator and industry\, improves regional understanding and contributes toward optimum resource recovery (via lower life-cycle costs and accelerated production opportunities). \nTable 1: Comparison between Australia’s offshore petroleum development characteristics in 1969 (first significant production) and 2020 (current). \n\n\n\n\n1969\n2020\n\n\nRegulatory Regime\n·         Petroleum (Submerged Lands) Act 1967 (PSLA) (implementation of)\n·         Offshore Petroleum and Greenhouse Gas Storage Act 2006 (OPGGSA)\n\n\nProduction focus\n·         Oil \n·         Gas into nascent (eastern) domestic infrastructure (e.g. pipelines)\n·         LNG (and condensate) export \n·         Domestic gas \n·         Oil\n\n\nDevelopment priorities\n·         Greenfield construction \n·         Vertically integrated developments (upstream and downstream alignment) \n·         Minimal third-party access considerations \n \n·         Brownfield construction (tiebacks\, re-use of existing pipelines\, facilities\, etc.) \n·         Predominantly vertically integrated developments \n·         Third-party access considerations \n·         Limited shared infrastructure\n\n\nBasin (development) characteristics\n·         Immature basins in the southeast (Gippsland Basin) and the northwest (Northern Carnarvon Basin)\n·         Mature basins in the southeast (Gippsland Basin) and the northwest (Northern Carnarvon Basin) \n·         Immature basins in the north (Browse Basin\, Bedout sub-basin and northeastern Bonaparte Basin)\n\n\nMarket characteristics\n·         Oil export for international markets and into local refineries \n·         Isolated eastern and (nascent) western domestic gas markets\n·         Well-established\, relatively isolated eastern and western domestic gas markets \n·         Domestic gas pricing increasingly linked to international markets \n·         Decreased local refining capability\n\n\n\n 
URL:https://www.spe-wa.org/event/spe-apogce-conference-preview-regulatory-challenges-and-opportunities-for-optimising-petroleum-resource-stewardship-in-offshore-australia/
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BEGIN:VEVENT
DTSTART;TZID=Australia/Perth:20201027T170000
DTEND;TZID=Australia/Perth:20201027T181500
DTSTAMP:20201006T003211Z
CREATED:20201004T071001Z
LAST-MODIFIED:20201006T003211Z
UID:24226-1603818000-1603822500@www.spe-wa.org
SUMMARY:SPE WA Professional Development Event - Toastmasters Club Demo Meeting
DESCRIPTION:Would you like to improve your confidence when presenting to others? Do you want honest and constructive feedback on how you could improve your communication skills? And Professional Development Opportunities?  \nToastmasters is coming to SPE WA! \nWhat is Toastmasters?  \nSince 1924\, Toastmasters International has
helped millions of men and women become more confident when communicating with others. The Toastmasters network of clubs and its learn-by-doing program were created to help you become a better speaker and leader. Why pay thousands of dollars for a seminar when you can join a Toastmasters club for a fraction of the cost to enjoy the state-of-art Pathways education program and have fun in the process? \nWhat’s in it for you? \nWhile some are born confident\, charismatic leaders\, most must work to develop their communication and leadership skills. Through Toastmasters\, you’ll learn the skills and practice them to become the leader and communicator you want to be. You will also sharpen your management skills\, become a better negotiator\, gain trust and inspire your team. Learn to be decisive. Belong to a prestigious international organization that produces renowned communicators and presenters. \nLearn more at our Demonstration Meeting! \nPlease register for this event to see what a typical Toastmasters Meeting is like. \nLearn more about what you need to do to become a member of the Petroleum Professionals Toastmasters Club in SPE WA. \nRegister via http://www.spe-wa.org/ \nDemo Meeting Details \n\nDate & Time: Tuesday\, 27th October 17:00-18:15 pm. \nVenue: Perth City Tavern (Total BS & Co.)\, 185 St Georges Terrace\, Perth. \nTicket: $10 (Inclusive 1 beer or soft drink after the demo meeting).\nSPE members and non-member guests are all welcome to attend the event. \n\nFor more information contact: \n\nPlease email our SPE WA Administrator Lynn Bird if you have any queries.\nFor information about Toastmasters\, you can visit https://www.toastmasters.org/.\nYou can learn more about all of SPE WA events via http://www.spe-wa.org/\n\nLooking forward to seeing you on the 27 October from 16:50 pm for 17:00pm start.  \nSPE WA Professional Development Committee
URL:https://www.spe-wa.org/event/spe-wa-professional-development-event-toastmasters-club-demo-meeting/
LOCATION:Perth City Tavern (Total BS&Co.)\, 185 St George Terrace\, Perth\, WA\, 6000\, Australia
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BEGIN:VEVENT
DTSTART;TZID=Australia/Perth:20201026T190000
DTEND;TZID=Australia/Perth:20201026T200000
DTSTAMP:20201014T083140Z
CREATED:20201014T082831Z
LAST-MODIFIED:20201014T083140Z
UID:24425-1603738800-1603742400@www.spe-wa.org
SUMMARY:26th Oct 2020 SPE WA Reducing Net Carbon Footprint Webinar: An Overview of Recent Liquid Hydrogen Projects at NASA Kennedy Space Center
DESCRIPTION:SPE WA are proud to present the details of our live webinar on Reducing Net Carbon Footprint titled “An Overview of Recent Liquid Hydrogen Projects at NASA Kennedy Space Center” presented by Adam M. Swanger! \nWebinar registration:\nhttp://www.spe-wa.org/event/26th-oct-2020-spe-wa-reducing-net-carbon-footprint-webinar-an-overview-of-recent-liquid-hydrogen-projects-at-nasa-kennedy-space-center/  \nNote that once you register on the website\, a separate email will be sent to you which has a link that takes you to the webinar specific entry gateway the day before the webinar. \nAbout the Presentation \nIn this presentation we will cover some recent and exciting LH2 projects from around NASA Kennedy Space Center (KSC) in Florida\, USA; both in research & technology as well as permanent infrastructure for rocket launch pads. A large-scale test of an Integrated Refrigeration and Storage (IRaS) system called the Ground Operations and Demonstration Unit for Liquid Hydrogen (GODU-LH2) will be discussed\, including the design\, hardware build-up\, and final results. A brief history and background of the cryogenic systems at KSC launch pads will also be presented\, as well as present usage\, and upgrades. Built in the 1960s to support the Moon missions of the Apollo Program\, Pads A and B have always boasted some of the world’s largest and most complex liquid hydrogen and oxygen storage and transfer systems. The Pad B storage systems remained relatively unchanged throughout the Space Shuttle program\, however\, future launch requirements of the current Space Launch System (SLS) demand more LH2 than the legacy tank could handle. In 2018\, NASA awarded a contract to construct an additional 4700 m3 capacity LH2 tank adjacent to the legacy one to meet the demand. Implementation of both IRaS and Glass Bubble technologies with the new LH2 sphere represents a landmark change in how the challenges associated with large-scale LH2 storage is addressed. \nAbout the Speaker – Adam M. Swanger \nAdam M. Swanger is a senior research engineer with the Cryogenics Test Laboratory at NASA Kennedy Space Center for energy efficient technology development and materials research. Mr. Swanger holds a Master of Science in Mechanical Engineering (Thermo-Fluids) from the University of Central Florida\, and a Bachelor of Aerospace Engineering from The Ohio State University. He has been working in the field of cryogenics for over ten years\, with a focus on providing practical solutions to low-temperature problems in both active and passive thermal systems. He has played an integral role in projects for NASA\, the Department of Energy\, the National Institute for Occupational Safety and Health\, and many commercial and industrial partners. His current research activities include solid-state thermo-fluid storage\, next-generation cryogenic propellant storage and densification\, and high-performance insulation systems for both terrestrial and in-space applications.
URL:https://www.spe-wa.org/event/26th-oct-2020-spe-wa-reducing-net-carbon-footprint-webinar-an-overview-of-recent-liquid-hydrogen-projects-at-nasa-kennedy-space-center/
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BEGIN:VEVENT
DTSTART;TZID=Australia/Perth:20201014T120000
DTEND;TZID=Australia/Perth:20201014T130000
DTSTAMP:20200915T132602Z
CREATED:20200914T044517Z
LAST-MODIFIED:20200915T132602Z
UID:24220-1602676800-1602680400@www.spe-wa.org
SUMMARY:SPE WA Professional Development WebinarIncreasing Career Effectiveness - Confessions of a Reformed Engineer
DESCRIPTION:SPE WA are proud to present the details of our live Professional Development webinar titled“Increasing Career Effectiveness – Confessions of a Reformed Engineer”Presented by https://www.spe-wa.org/wp-content/uploads/2020/01/Nopsema2-1.png Smart (RightTime Technologies\, SPE WA) \nWebinar registration: CLICK HERE TO REGISTER \nAbout the Presentation\nIn this presentation\, https://www.spe-wa.org/wp-content/uploads/2020/01/Nopsema2-1.png will share career experiences that have shaped how he understands what it means to be an effective contributor in organisations.  \nBuilding on his recent experience helping major resource companies with their digital transformation ambitions\, https://www.spe-wa.org/wp-content/uploads/2020/01/Nopsema2-1.png will first discuss the opportunities offered by cutting-edge technology. He will then share an example of “textbook” project delivery and how this can be improved upon\, the necessity of change leadership and the key role of people skills in achieving objectives. He will also discuss risks around “step change” initiatives and the hazards of ego-driven Leadership. He will then discuss this in relation to complex adaptive systems and how Systems Thinking approaches can help you to be effective in large organisations.  \nFinally he will share 10 observations that may help you in your career journey. \nAbout the Speaker – https://www.spe-wa.org/wp-content/uploads/2020/01/Nopsema2-1.pngn Smart\n\nhttps://www.spe-wa.org/wp-content/uploads/2020/01/Nopsema2-1.png Smart is an experienced Consultant who works with leadership teams in Oil & Gas and Mining companies to realise innovation and digital transformation initiatives. Fluent in business process\, production operations and Information Technology management\, https://www.spe-wa.org/wp-content/uploads/2020/01/Nopsema2-1.png has helped organisations to leverage digital technologies\, renew business and operating models\, and realise organisational renewal. His previous clients include BHP\, Chevron\, Woodside\, INPEX\, Santos and Petronas. \nhttps://www.spe-wa.org/wp-content/uploads/2020/01/Nopsema2-1.png currently runs an independent consulting company\, RightTime Technologies\, that helps business to realise the opportunities offered by Digital Transformation. He is the current Chairman of the Society of Petroleum Engineers Western Australia\, a former Board member of the Entrepreneurs’ Organisation WA and in 2019 was Co-Chair of the SPE Asia Pacific Digital Week held in Kuala Lumpur. \nhttps://www.spe-wa.org/wp-content/uploads/2020/01/Nopsema2-1.png holds a double degree in Mechanical Engineering and Commerce from the University of Western Australia\, a Graduate Diploma in Computer Science from Curtin University\, and has recently completed his MBA studies at the University of Western Australia. He lives in Perth\, Western Australia with his wife Suzanne and children\, Emma and Len.
URL:https://www.spe-wa.org/event/spe-wa-professional-development-webinar-increasing-career-effectiveness-confessions-of-a-reformed-engineer/
LOCATION:Online\, WESTERN AUSTRALIA\, 6008\, Australia
ATTACH;FMTTYPE=image/jpeg:https://www.spe-wa.org/wp-content/uploads/2020/09/martin-adams-a_PDPUPuNZ8-unsplash-scaled.jpg
END:VEVENT
BEGIN:VEVENT
DTSTART;TZID=Australia/Perth:20201008T120000
DTEND;TZID=Australia/Perth:20201008T130000
DTSTAMP:20200922T114316Z
CREATED:20200922T095458Z
LAST-MODIFIED:20200922T114316Z
UID:24280-1602158400-1602162000@www.spe-wa.org
SUMMARY:8th October 2020 SPE WA Webinar - An innovative Well completion program to reduce risk and costs
DESCRIPTION:SPE WA are proud to present the details of our live webinar on well completions titled “Interventionless actuated completions reduce risk and costs” presented by Ms. Susanne Loen Ommundsen from Interwell Norway! \nWebinar registration:\n8th October 2020 SPE WA Webinar – An innovative Well completion program to reduce risk and costs \n \nNote that once you register on the website\, a separate email will be sent to you which has a link that takes you to the webinar specific entry gateway the day before the webinar. \nAbout the Presentation\nIntervention during the Completion deployment phase can be challenging\, time consuming\, and can increase risk exposure during execution. By utilising step changes in oilfield technology Wells can be completed intervention free whilst adhering to strict barrier guidelines without compromising integrity or Production. This technique allows Completions to be run quicker and allows top side equipment to be commissioned before bringing the Well online without the need for a Rig.  A Norwegian operator implemented an improvement program focused on increasing efficiency on platform well operations. Utilising dual remotely activated full-bore barrier valves saved them hours per well whilst reducing human exposure. \nAbout the Speaker\n \nSusanne Loen Ommundsen holds a combined degree in Petroleum and process technology from University of Bergen and is working as Business Development Manager for the Completion department based in Stavanger\, Norway. She has been in the industry for more than 10 years’ experience in offshore and onshore operations consist of Coil tubing and Completion operation with tools such as barrier solutions\, fiber optic monitoring\, gas lift\, chemical injection\, screens. Susanne joined the team in interwell as completion sales engineer and has been a part of the growth of the Completion business globally\, and expanding the Completion portfolio with the main target to achieve an efficient completion to post completion installation.  In the spare time Susanne spends her time with her husband and two beautiful children.
URL:https://www.spe-wa.org/event/8th-october-2020-spe-wa-webinar-an-innovative-well-completion-program-to-reduce-risk-and-costs/
ATTACH;FMTTYPE=image/jpeg:https://www.spe-wa.org/wp-content/uploads/2020/09/1.jpg
END:VEVENT
BEGIN:VEVENT
DTSTART;TZID=Australia/Perth:20200930T190000
DTEND;TZID=Australia/Perth:20200930T200000
DTSTAMP:20200916T144205Z
CREATED:20200916T143642Z
LAST-MODIFIED:20200916T144205Z
UID:24238-1601492400-1601496000@www.spe-wa.org
SUMMARY:30th Sept 2020 SPE WA Reducing Net Carbon Footprint Webinar: CO2 storage experiences in carbonates
DESCRIPTION:SPE WA are proud to present the details of our live webinar on Reducing Net Carbon Footprint titled “CO2 storage experiences in carbonates” presented by Dr. J. Carlos de Dios! \nWebinar registration:\nhttp://www.spe-wa.org/event/30th-sept-2020-spe-wa-reducing-net-carbon-footprint-webinar-co2-storage-experiences-in-carbonates/  \nNote that once you register on the website\, a separate email will be sent to you which has a link that takes you to the webinar specific entry gateway the day before the webinar. \nAbout the Presentation\nMost of CO2 geological storage projects worldwide correspond to sandstones in porous media. Carbonate study cases are less common\, and usually show a double permeability (i.e porous matrix and fractures) because of their petrophysical properties. The existence of a primary and secondary porosity conditions the hydraulic behaviour of these reservoirs and CO2 plume evolution. The injection also impacts on the petrophysical properties due to mechanical effects and the reactivity of the mixture CO2+resident brine with the carbonated matrix and fracture fillings. Experiences on CO2 injection at Hontomín Technology Development Plant (Spain)\, a naturally fractured carbonate reservoir\, are showed in the presentation. \nAbout the Speaker – Dr. Carlos Dios\nDr. J. Carlos de Dios is the Chief Operation Officer in Fundación Ciudad de la Energía-CIUDEN F.S.P. for CO2 geological storage\, with full accountability as partner of the project OXYCFB300-Compostilla\, one of most innovative CCS (Carbon Capture Storage) ventures around EU. Director of Spanish CO2 Geological Storage project in a deep saline aquifer and expertise in management of Thermal Generation Plants for CO2 capture\, and in general in combustion processes. Successful experience in international project partnership for 30 years in energy\, mining and environmental sectors. Inventor of  industrial patents\, author of scientific articles and lecturer in university courses and masters of Technical University of Madrid\, Technical University of Paris\, Norwegian University of Science and Technology\, University of Cagliary and University of Carlos III. He holds a PhD degree in Mining and Energy Engineering from Technical University of Madrid.
URL:https://www.spe-wa.org/event/30th-sept-2020-spe-wa-reducing-net-carbon-footprint-webinar-co2-storage-experiences-in-carbonates/
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DTSTART;TZID=Australia/Perth:20200921T110000
DTEND;TZID=Australia/Perth:20200921T120000
DTSTAMP:20200903T010741Z
CREATED:20200807T021703Z
LAST-MODIFIED:20200903T010741Z
UID:23843-1600686000-1600689600@www.spe-wa.org
SUMMARY:September 2020 SPE Distinguished Lecturer Webinar - Techniques to Reduce Operating Costs for Increased Reserves and Profitability
DESCRIPTION:SPE WA are proud to present the details of our webinar on “Techniques to Reduce Operating Costs for Increased Reserves and Profitability” by SPE Distinguished Lecturer\, Philip Hart! \nRegister for Distinguished Lecturer virtual event for SPE Members: \nREGISTER HERE\nAbout the Presentation \nEmploying certain practices in past field operations reduced operating costs by over $4.4MM per year and helped increase reserves by more than 3 million barrels of oil (MMBO). These practices are broken into three main topics: \n\nImproving expense accounting accuracy and details\nFocusing on incremental individual operating costs to improve investment decisions\nImplementing innovative expense reduction techniques\n\nThe brief accounting overview concentrates on simplifying invoice coding\, creating detailed equipment expenses\, and developing more precise allocations. These improvements allow “troublesome” equipment to be identified and optimized\, while providing improved financials. \nThe focus on determining individual operating costs allows shut-in wells to return to profitable production\, pinpoints wells losing money\, and improves the economics of workovers and new drill wells. Using this approach\, one field increased reserves by more than 3 MMBO. \nLastly\, nine operational techniques that reduced costs are reviewed in detail (and 10 more highlighted). These applications reduced pumping failures by 61% (saving $2.1MM/year)\, decreased energy costs by $1.3MM/year\, and saved other expenses by $1.0MM/year. \nWith accurate detailed accounting\, incremental individual well cost analysis\, and cost cutting efforts\, a field’s cash flow and reserves can be increased substantially. \nAbout the Speakers – Philip Hart\n \nPhilip Hart\, as President of Excalibur Ventures\, provides consultations to improve fields through Reservoir and Operational Studies and also designs oilfield equipment for Omega Technologies in Houston\, Tx. \nHe started optimizing fields in 1978 as an Exxon Engineer\, taught schools around the world\, wrote SPE and SPWLA papers\, and was President over companies that operated 2\,300 wells. \nWorking with innovative teams\, Philip oversaw costs being reduced from $45MM to $25MM per year\, while raising production from 13\,500 to 19\,000 BOPD and increasing valuations from $45MM to more than $300MM. \nBesides uncovering oilfield gems\, he enjoys mission work and family time.
URL:https://www.spe-wa.org/event/september-2020-spe-distinguished-lecturer-webinar-techniques-to-reduce-operating-costs-for-increased-reserves-and-profitability/
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