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- Volume 36, Issue 2, 2018
First Break - Volume 36, Issue 2, 2018
Volume 36, Issue 2, 2018
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Reservoir characterization of the Triassic Kobbe and Snadd formations — Bjarmeland Platform, Norwegian Barents Sea
Authors Jørgen André Hansen and Nazmul Haque MondolAbstractA reservoir characterization study of the Triassic Kobbe and Snadd formations is carried out in the Bjarmeland Platform area, Norwegian Barents Sea, through detailed petrophysical analysis and rock physics diagnostics. Results are tied to depositional environments and discussed in the context of burial depth and cementation as present burial depth is less than maximum burial depth due to upliftment. Marginal marine sandstones in the Snadd Formation display marginally better reservoir quality on average than those of fluvial origin, yet higher quality individual reservoirs are observed within both facies. As expected, the Kobbe Formation reservoirs are consistently poorer. The sensitivity of existing rock physics models to the data is shown to be reasonably valid (via porosity, water saturation, shale volume). Snadd Formation reservoir sandstones not affected by cementation are only observed at shallow depth in the west of the study area. This is supported by comparison to an experimental compaction trend as well as rock physics models. All Kobbe Formation reservoir units show consistent signs of chemical compaction due to deeper burial. The main findings of this study are estimates of important reservoir properties and examples of how results from petrophysical analysis are validated and complemented in various rock physics domains.
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Optimizing hydraulic fracturing operations through time-lapse, multi-component and microseismic monitoring
Authors Thomas L. Davis and Oscar QuezadaAbstractThe future of shale reservoir development is dependent on our ability to use integrated technologies to improve the recovery factor. By characterizing the reservoir under dynamic rather than static conditions we can monitor the enhanced permeability field created by the hydraulic fracturing process. Natural fractures, faults and stress state profoundly influence the permeability field created by hydraulic fracturing. The permeability field is a continuum and is constantly changing as the reservoir is developed. Monitoring these changes can lead to an understanding of the enhanced reservoir volume surrounding stimulated wellbores while enabling a better estimation of the effectiveness of the hydraulic fracturing process in shale reservoirs.
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Microseismic data interpretation — what do we need to measure first?
Authors Leo Eisner and František StaněkAbstractCurrently, there are four widely discussed theories used to describe how microseismicity interacts with hydraulic fracturing. Each theory has a different implication for the interpretation of microseismicity used for reservoir modelling. Therefore, better understanding of the relationship between microseismicity and hydraulic fracture stimulation is needed before further reservoir models are developed and applied. This would lead to a more precise estimation of hydrocarbon production and give greater value to microseismic data. We may use either seismic or non-seismic methods. While non-seismic methods provide an independent view of hydraulic fracturing they only provide a limited amount of information on the relationship between hydraulic fracturing and microseismicity. We propose micro-seismic monitoring of directivity as the most promising way to determine the orientation of fault planes and associated slip vectors. Although this is a suitable method it requires sensors in multiple azimuths that are well coupled to obtain reliable high frequency signals. We suggest using Distributed Acoustic Sensing (DAS) sensors which are capable of sampling high frequencies and may provide continuous data along long offsets at reasonable costs.
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Suggested best practice for seismic monitoring and characterization of non-conventional reservoirs
Authors Marco Bohnhoff, Peter Malin, Jan ter Heege, Jean-Pierre Deflandre and Charles SickingAbstractGeneral awareness of induced seismicity and gas leakage related to energy reservoir exploitation has been on the rise for several years (McGarr, 2002; Davies et al., 2013). This includes events from short-term fluid injection for reservoir simulation (Giardini, 2009; Atkinson, 2016), Long term hydrocarbon extraction (Van Thienen-Visser and Breuness, 2015), underground storage of natural gas (Cesca et al., 2014), waster water (Ellsworth, 2013), and carbon dioxide (Zoback and Gorelick, 2012). High rates of felt induced events in previously quiet areas are now considered critical for public safety and social licence to operate (Petersen et al, 2016). Concerns about contamination of ground water and climate effects have followed suit (Darrah et al., 2014; Davies et al., 2014).
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How to establish an integrated production management system across the reservoir lifecycle
More LessAbstractSuccessful reservoir management today is inextricably linked with the field’s production system and a complete evaluation of the behavior of that system throughout the reservoir lifecycle.
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A new approach to compensate for illumination differences in 4D surveys with different individual acquisition geometries
Authors Didier Lecerf and Martin BesselievreAbstractSuccessful time-lapse (or 4D seismic) studies require special care when it comes to the removal of undesirable artifacts caused by the differences in acquisition geometries. By attempting to repeat the source and receiver geometries between surveys as precisely as possible any subsequent 4D noise is minimized so that subtle seismic signal variation induced by reservoir production can be detected. It is commonly accepted that the required repeatability accuracy is directly linked to the desired sensitivity and resolution of the 4D signal. Illumination studies prior to any 4D experiments ensure that the reservoir is illuminated in as identical a fashion as possible between base and monitor survey so that the desired 4D effects can be recovered. In fact, it is common practice to plan and design 4D surveys with optimal acquisition repeatability in mind.
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Toward the global tectonic model: A new hope (part 2)
Authors Neil Hodgson and Karyna RodriguezAbstractWe all sense that ultimately ‘nature’ knows best. While we have tried to impose simple models and ordered processes on the world’s geology, we actually continue to encounter nature’s myriad uniqueness. As a result, we have grown comfortable with the butterfly effect of multiple influences randomly expressed at any scale from hand-sample to plate. We observe subsidence occurring offshore Argentina or Somalia while uplift occurs offshore Namibia and assume this is due to local tectonics acting ineffably and unconnectedly. That a sequence is deposited in a stable depositional regime in Angola while shelf collapse and instability produces the geology observed offshore Namibia is more troubling, but such contrasting tectonics acting simultaneously is again an expression of local plate stresses acting on local geology with non-linear results. This is our experience, so we understand our basin geologies on an isolated basin scale. With no common glue of a process we rely on an understanding of local basin tectonics. And this works but are we missing something?
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Volumes & issues
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Volume 42 (2024)
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Volume 41 (2023)
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Volume 40 (2022)
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Volume 39 (2021)
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Volume 38 (2020)
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Volume 37 (2019)
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Volume 36 (2018)
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Volume 35 (2017)
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Volume 34 (2016)
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Volume 33 (2015)
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Volume 32 (2014)
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Volume 31 (2013)
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Volume 30 (2012)
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Volume 29 (2011)
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Volume 28 (2010)
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Volume 27 (2009)
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Volume 26 (2008)
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Volume 25 (2007)
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Volume 24 (2006)
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Volume 23 (2005)
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Volume 22 (2004)
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Volume 21 (2003)
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Volume 20 (2002)
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Volume 19 (2001)
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Volume 18 (2000)
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Volume 17 (1999)
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Volume 16 (1998)
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Volume 15 (1997)
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Volume 14 (1996)
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Volume 13 (1995)
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Volume 12 (1994)
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Volume 11 (1993)
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Volume 10 (1992)
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Volume 9 (1991)
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Volume 8 (1990)
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Volume 7 (1989)
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Volume 6 (1988)
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Volume 5 (1987)
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Volume 4 (1986)
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Volume 3 (1985)
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Volume 2 (1984)
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Volume 1 (1983)