official show daily of the 80th eage conference and … · 2018. 6. 12. · e&p daily news •...
TRANSCRIPT
Living in an Age of Energy Uncertainty
Recognition for EAGE’s Shining Lights
BY MARK VENABLES, CONTRIBUTING EDITOR
The oil and gas sector is going through yet another transi-tion. Having emerged as fitter and leaner after the low-
er-for-longer era forced operators to improve operational efficiency, they are now facing key strategic decisions about meeting an uncertain demand for oil and ensuring that their businesses are fit for the future by investing in renewables.
The two representatives on the panel from operators both have salient stories to tell about their companies’ future di-rection. Jez Averty, senior vice president, development and production, Norway for Equinor, explained that the harsh reality of the future of energy is that it is uncertain. “Its di-rection, speed and breadth are all uncertain outcomes,” he said. “According to our energy outlook, the world in 2050 could range from 60 to 120 million barrels of oil a day.”
The reality of the day is that the market is sending mixed signals. On one hand, carbon prices are beginning to in-crease in many parts of the world, electric vehicle (EV) sales are booming and 2017 saw record figures set for the generation of both solar and wind as costs decrease. But on the other hand, there was also an increase in the demand for coal and oil, while CO2 emissions continue to rise.
What is Equinor doing to respond? “We revised our
strategy that can be described as high value, always safe and low carbon,” Averty added. “We are on a journey, evolving into a new energy company and have even gone as far as changing our name.”
For its part, Total is two years into an ambitious 20-year plan that states that 20% of its production will be from renewable sources, but as Arnaud Breuillac, president of ex-ploration and production at Total, explained, the company felt no need for a name change. “We believe, and we have said this for quite some time, we should not confront en-ergy sources with each other; we need all of them. We have set the IEA’s 2oC scenario as a point of reference for us and this influences our decisions on how energy will be produced in the future.”
Paul McConnell, research director at Wood McKenzie, cautioned the industry not to be passive. He pointed to the disruptive influence that the smartphone has had over the 10 years since its introduction as a warning to the oil and gas sector not to be complacent. “It came from nowhere and in 10 years you had a number of very well-established business models that were completely disrupted,” he said. “Many people in those businesses did not see that threat coming. The dominance they held in their industries did not prevent them from being hit hard.”
He called this the age of demand. He explained that the biggest challenge for oil and gas companies is that there is very little they can do to control oil demand. “If EVs become as cheap as ordinary cars people will start to buy them; there is nothing that any oil producer can do about that,” he said. “Then the question is how do you respond to a market where your primary customer base is starting to evaporate?”
He argued that this transition is fundamentally a demand story. “The march of new technology imposing itself on the landscape of energy demand has no regard for what was there before,” McConnell concluded. “We have seen the record low cost of solar broken seven times in the last two years, offshore wind is reducing in cost extremely quickly and EVs, although still a small percentage of the overall vehicle population, are promising great things. Customers will decide the future.”
Averty added one further thought in that it was not dis-ruption the market was facing but a revolution. “The rea-son I say that is even if we assume there is a reduction in world demand and an increase in renewables for electricity, I think it’s very important to remember that the scope and size of the change needed to get to the 2oC scenario will require a revolutionary rate of change,” he said. n
E&P DAILY NEWS • J U N E 1 3 , 2 0 1 8 • W E D N E S D AY
2018 EAGE Conference & Exhibition
COPENHAGEN WEDNESDAY
DAILYNEWSOFFICIAL SHOW DAILY OF THE 80TH EAGE CONFERENCE AND EXHIBITION
The opening debate at EAGE took a look at the role that oil and gas will play in the energy transition era.
A highlight of the opening ceremony at EAGE was the annual awards ceremony.
The Official Show Daily of EAGE 2018Visit the Hart Energy booth or online at EPmag.com.
E&P Daily News is edited by the staff of Hart Energy, an information provider for the global
energy industry. Opinions herein do not necessarily reflect the opinion of the organizer or Hart Energy.
I N S I D E T H I S I S S U E
3 SCHEDULE OF EVENTS
4 NEW POSSIBILITIES IN DEEP WATER
5 CSEM WELL CALIBRATION STUDY LAUNCHED
7 THE VALUE OF SEABED SEISMIC
8 INCREASING THE BUSINESS VALUE OF E&P DATA
10 EXHIBITION FLOOR PLAN
BY MARK VENABLES, CONTRIBUTING EDITOR
Among the 14 awards presented for outstanding achievement to members of the EAGE by HRH
Prince Joachim of Denmark, two stood out. First, the Arie Van Weeldon Award is bestowed on someone under 30 in recognition of a highly significant contribution to one or more of the disciplines. This year’s award was presented to Lucas Pimienta for his outstanding experimental work as a young scientist in rock mechanics.
“I am an experimental rock physicist,” Pimienta said. “My research has been to select rock samples to investigate their different physical properties, how they correlate and how they are affected by different factors. Over the years I have been blessed with meeting and learning from amazing sci-entists who I owe a lot to. I will try my best to be worthy of this award in the future.”
The Alfred Wegener Award is presented to a member of the EAGE who has made an outstanding contribution over a period of time to the scientific and technological advance-ment of petroleum geoscience and engineering.
The award was given to Tiziana Vanerio, who explained
that her interest in geoscience began at an early age. “I grew up near a volcano and had to flee my own town in terror because we feared an eruption, but fears and facts must be faced and that is what lay the foundation for a career in geo-physics,” she said. “Today I am a rock physicist and I work to understand how interaction affects the providence of rocks and geomaterials.
“One of the most rewarding aspects of my work is watch-ing students begin to grasp rock science and turn into detec-tives as they hunt out the clues. One of my goals has been to make experimentation more interesting to students, and to do that I have created an online lab that reproduces the instrumentation in my rock physics lab guiding students through data acquisition and experimentation.
“As the first female scientist to receive this distinction I hope I will inspire more young women to pursue earth sci-ences, a field that is ever more important,” she said.
The Conrad Schlumberger award is presented to a mem-ber who has made an outstanding contribution over several years to geophysics. This year there were two recipients. The first winner was Philip Christie for his outstanding ability to embrace the understanding of earth properties through scientific research and innovative design technology.
“Cambridge is a great place for research and I’ve spent much of my career there from the time I was designing and operating seabottom seismometers to my present role as sci-entific advisor to Schlumberger,” he said.
Christie was originally a physicist but entered earth sci-ences as a means to travel and see the world; however, he got hooked on the thrill of seeing subsurface geology that no one had ever seen before.
“For me, it was like walking through fresh snow and I still get a huge rush of dopamine every time I see a new seismic dataset,” he added.
The second recipient was Johan Robertsson from ETH Zurich. “It means a lot to me that so many of the outstanding colleagues who have been so critical and inspirational to me nominated me for this award,” he said.
The EAGE also made a student’s award. The Laurie Dake Challenge was created to promote cross‐disciplinary geosci-ence and engineering integration within universities. The teams are required to analyze and propose a field develop-ment plan for a discovered hydrocarbon resource. All teams work with the same dataset, which is provided by a different company each year. This year’s winner was the team from the Memorial University of Newfoundland, Canada. n
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3E&P DAILY NEWS | J U N E 13 , 2 018 | W E D N E S D AY
SCHEDULE OF EVENTS
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Wednesday, June 13
07:30 – 18:00 Registration Registration area08:30 – 11:00 Executive Session: “Integration of disciplines for a more efficient E&P industry” Auditorium 1508:30 – 17:10 Technical program (oral presentations) Conference area08:30 – 17:10 e-Poster presentations e-Poster area09:00 onward Breakfast at the exhibition Exhibition floor09:00 – 17:30 International Prospect Center Program Exhibition floor, booth 186009:00 – 17:30 Student program EAGE Community Hub, booth 41009:00 – 17:30 Exhibition09:30 – 13:00 HPC Area Exhibition theatre 12:30 – 13:00 “Growth, Energy, Climate: Beyond the Squaring of the Circle,” by Dr. Philippe Charlez. EAGE Community Hub, booth 41013:00 –16:30 Digital Transformation Area Exhibition theatre14:30 –15:30 Annual General Meeting for Members Treehouse 16:00 – 18:00 Session for Young Professionals Treehouse16:00 onward Afternoon drinks at the exhibition Exhibition floor16:30 – 17:30 Start-Up Area Exhibition Theatre 19:00 – 23:30 Conference evening Lokomotivvaerkstedet
Conference Highlights–Wednesday, June 13“Growth, Energy, Climate: Beyond the Squaring of the Circle,” by Dr. Philippe Charlez12:30 – 13:00, EAGE Community Hub, booth 410Since the beginning of the industrial revolution, eco-nomic growth has been fueled by energy and more par-ticularly by fossil fuels, which today represent 82% of the global energy mix. But through this consumption, economic growth is also a hazardous process that emits anthropogenic CO2, the main cause of climate change.
Modern society would thus be confronted with para-doxical objectives: to satisfy a growing demand for en-ergy, to ensure the economic growth of a world pop-ulation growing sharply while reducing greenhouse gas emissions to solve the problem of climate change. Growth, energy and climate: Can the energy transition solve the squaring of the circle?
Dr. Charlez is an energy expert and also the author of several books. After the talk, audience members can en-ter a draw for a copy of his books “Our Energy Future is Not Set in Stone” and “The Shale Oil and Gas Debate.”
Session for Young Professionals15:00 – 17:00, TreehouseFollowing last year’s success, delegates under the age of 35 years are once again invited to a special session focus-ing on young professionals. The session will commence with two keynote speeches, followed by the introduc-tion of interactive roundtable session leaders. Building on the success of last year’s break-out sessions, the in-teractive sessions will be highly engaging and an excel-lent opportunity to learn valuable skills for the further development of your career.
Although tailored for our young professionals com-munity, we encourage all delegates to join.
Conference Evening19:00 – 23:30, LokomotivvaerkstedetEntrance to this wonderful evening is included in the full delegates and family members registrations. Let’s share a drink, a nice meal and a dance together. Make sure to collect your conference evening rib-bon and invitation at the EAGE Community Hub booth 410. Others interested in attending the con-ference evening can do so by buying a ticket at the registration desk.
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4 W E D N E S D AY | J U N E 13 , 2 018 | E&P DAILY NEWS
Sparse Node Acquisition Opens New Possibilities in Deep Water High-quality subsalt imaging can be achieved with a much wider separation than today’s standard.
BY PAUL DOCHERTY, FAIRFIELDNODAL
To date, growth in deepwater ocean bottom node (OBN) acquisition has been driven by the widespread
adoption of time lapse, or 4-D, seismic for reservoir man-agement. For example, all of FairfieldNodal’s deepwater OBN surveys in the last 15 years have been either baseline or 4-D monitor surveys. During this time there have been continuous improvements in node deployment and re-trieval technologies as well as in the nodes themselves. As a result, in a recent survey in the Gulf of Mexico (GoM), FairfieldNodal achieved an average deployment rate of 120 nodes/d and a peak rate of 200 nodes/d in 2,200 m (7,218 ft) of water.
Numbers like these, along with the proven quality of node data, have naturally led to considerations of new roles for nodes. Below are two initiatives involving sparse nodes, that is, nodes deployed with spacings much larger than are typical.
Even today’s 4-D surveys, with node spacings at around 400 m (1,312 ft), might be thought of as sparse. However, it has been demonstrated that high-quality subsalt imag-ing can be achieved with a much wider separation. The accompanying figure compares two images obtained at the deepwater Julia Field in the GoM. One has nodes at 400 m and the other has nodes at 800 m (2,625 ft). The same dense source grid, 50 m by 50 m (164 ft by 164 ft), was used for both images. While there has been no attempt at signal enhancement on the 800-m image (only a simple scale factor has been applied), it’s clear that the same sub-salt structures are revealed with just one-quarter of the nodes. Besides image, a key question is whether a veloc-ity model can be determined from such sparsely sampled data. FairfieldNodal’s experience has been that it can be; in fact, angle gathers constructed for the 400-m and 800-m Julia data yield almost identical residual moveout picks. This means that standard tomographic techniques can be expected to obtain a similar estimate of the model from either node geometry. For Julia it’s also worth noting that model building was accomplished without a starting mod-el; only water velocity was given. The implication is that not only can sparse nodes yield a quality image, but that the image can be obtained in areas new to exploration. This initiative, exploration with nodes, is expected to ex-pand the OBN market in the future.
The second initiative is the so-called velocity survey. Also sparse on the node side, the velocity survey goes far-ther and employs sparse shots as well. Source line spacings of one hundred to several hundred meters are envisaged. Unlike exploration with nodes, no image is obtained. The velocity survey acquires data with the sole purpose of building a more accurate velocity model. The improved model can then be used to better image existing data, ei-ther streamer or node. The enabling data processing tech-
nology is full waveform inversion (FWI). FWI seeks to add the long wavelength components missing from current models; however, it requires data that contain the missing information to do so. The critical data are turning waves. These waves propagate through, rather than reflect from, structures of interest. Since turning waves tend to travel large distances from the source before emerging back at the seabed, long offsets are required. At Julia, for example, the reservoir is at a depth of around 9 km (5.6 miles). Off-sets approaching 30 km (19 miles) would likely be neces-sary to capture turning waves penetrating to this depth. Extreme perhaps, but offsets like this are being discussed. Add long offsets at all azimuths, and the velocity survey can become enormous. Fortunately, FWI typically works at frequencies below 10 Hz to15 Hz which makes sparse-ness acceptable and the velocity survey economically fea-sible. Whether or not FWI lives up to its promise in this case remains to be seen, but the industry should have an answer in the next year or two.
For more information, visit FairfieldNodal during EAGE at booth 1420. n
These 30-Hz reverse time migration images are from the Julia Field in the deepwater GoM. Image a is from 400-m node spacing, and image b is from 800-m node spacing. The two images compare favorably even though only one-quarter of the nodes contributed to the sparse image shown in b. (Image courtesy of FairfieldNodal)
Executive Session IIThursday, June 14“Integration of Disciplines for a More Efficient E&P Industry.” 08:30 – 11:00
This session will be focused on Europe, touching all the previous topics when applied to European explo-ration plays. It includes how Europe will respond to energy challenges (technology, business, community, energy alternatives, affordable energy) and how Eu-rope is contributing to meeting the energy need of the world’s growing population. The discussion will focus on the importance of a balanced portfolio to de-risk E&P operations.
Chairpersons:Isabelle Billat (VP Exploration NSR, Total) andNicholas Ashton, (SVP Exploration Norway and UK, Equinor)
Speakers:Alexey Vashkevich (Head of Geo Exploration, Gazprom Neft)Gro Haatvedt (EVP Exploration, AkerBP)Manfred Boeckmann (SVP Exploration, DEA Deutsche Erdoel AG)Martin Rune Pedersen(VP Norway, Denmark and the Netherlands, Total)Milly Tornaghi (VP Exploration & Services, Edison)Nick Richardson (Head of Exploration & New Ventures, OGA)Tristan Aspray (VP Europe, Russia, Caspian, ExxonMobil)Gaute Erichsen (Energy Counsellor at The Mission of Norway to the EU) The Executive Sessions are open to all registered EAGE 2018 attendees. n
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5E&P DAILY NEWS | J U N E 13 , 2 018 | W E D N E S D AY
Global CSEM Well Calibration Study LaunchedA calibration catalogue gives a unique opportunity for energy companies to access CSEM performance indicators.
CONTRIBUTED BY EMGS
EMGS has approximately 130,000 sq km (50,000 sq miles) of 3-D CSEM and 7,900 km (5,000 miles) of
2-D CSEM in its multiclient library data. The 3-D CSEM dataset covers about 300 exploration wells from different sedimentary basins with a variety of reservoir types, burial depths and geological age. Energy companies are invited to use this data to gain valuable insight into the potential of CSEM and by their own assessment see how CSEM can add value in exploration and to realize its de-risking potential.
The objective of such a study is to perform a look back for several calibration points (exploration well versus CSEM data) to aggregate findings and gather CSEM performance data. This will drive better understanding of the applica-bility of CSEM for future prospect evaluation. To achieve this, it is important that all CSEM inversion products are generated with the same approach and that all calibration points are evaluated using a consistent workflow. Findings from several calibration points can then be catalogued and provide comparable information for different play types and basins. Furthermore, such a consistent approach results in a catalogue that allows companies to perform a statistical analysis of CSEM performance, assuming a sufficient num-ber of calibration points. To ensure success of the project, close collaboration between EMGS and the energy com-pany domain experts is important.
The workflow applied to each calibration point aims to deliver a CSEM inversion result together with indicators of the CSEM information quality, e.g., inversion misfit, sensi-tivity to target and evaluation of the acquisition parameters. The inversion result is then analyzed together with the seis-mic information to provide observables that are commonly used in integrated CSEM interpretation to establish the likelihood of a prospect being hydrocarbon-charged and the
size/area of a possible hydrocarbon accumulation. Such in-terpretation observables include the presence or absence of an anomaly; anomaly size and depth; anomaly correla-tion with seismic observations, e.g., conformance to struc-ture and/or seismic direct hydrocarbon indicators, etc. The CSEM inversion result and interpretation observables are then compared to the well results to establish the level of correlation and consistency between the CSEM informa-tion and “ground truth.” Furthermore, there will be a vali-
dation step involving scenario testing to quantify the level of agreement between the CSEM inversion result and the post-drilling geological model for the well.
The selection of calibration points is based on client needs, interest and other available data. The calibration cat-alogue gives a unique opportunity for energy companies to access CSEM quality-approved performance indicators, which in turn will guide the use and applicability of CSEM data. For more information, visit EMGS at booth 600. n
Red dots indicate available exploration wells covered by 3-D CSEM data. In total, 303 exploration wells are covered by 3-D CSEM data. (Image courtesy of EMGS)
Pull your data from the
Geospace GCX-C (data-cloud)_EAGE Program Ad.indd 1 5/2/2018 11:50:40 AM
Learn more at slb.com/petrel
Faster, Better, Smarter E&P DecisionsThe Petrel* E&P software platform is now available in the DELFI* cognitive E&P environment. Through the utilization of a secure, cloud-based environment, we give you access and flexibility to more science and collaboration in the Petrel platform than ever before to help you make better, smarter decisions.
*Mark of Schlumberger. Copyright © 2018 Schlumberger. All rights reserved. 18-IS-405942
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6 W E D N E S D AY | J U N E 13 , 2 018 | E&P DAILY NEWS
New Imaging Identifies Shallow HazardsProcess allows site surveys with standard seismic data.
CONTRIBUTED BY PGS
Existing 3-D seismic data are being processed by PGS in a new way to deliver high-resolution images for shallow
hazard assessments, saving oil and gas companies time and money. An innovative reprocessing sequence is applied to GeoStreamer dual-sensor data, even if originally acquired for exploration purposes, to deliver images that compare with those of dedicated site surveys. However, GeoStream-er SHAZ data are significantly richer in low frequencies, meaning the spatial resolution is even better and the robust amplitude versus offset attributes de-risk shallow gas detec-tion. This bespoke SHAZ workflow works particularly well in shallow and medium water depths.
Prior to any drilling operation, site surveys need to be carried out to minimize the risk of harm to personnel and equipment and to protect the natural environment. The objective of any such site survey is to identify all pos-sible constraints and hazards from man-made, natural and geological features that might affect the operational or environmental integrity of a proposed drilling operation and to allow appropriate operational practices to be put in place to mitigate any risks identified.
In addition to side-scan sonar acoustic seabed imagery, various seismic surveys have traditionally been used to map out the overburden immediately beneath the seabed. The survey types can vary from conventional 3-D seismic to ultrahigh resolution 2-D or 3-D.
In deeper water settings conventional seismic surveys are typically used for shallow hazard evaluation by in-creasing the sampling rate to 2 ms and by reducing the bin spacing of the subsurface image compared to stand-ard 3-D imaging.
Minimizing acquisition footprintsIn shallower water depths the lack of near-offset infor-mation in conventional 3-D seismic is a limiting factor, leading to the overburden often being imaged at high reflection angles and resulting in image gaps that are vis-ible as significant acquisition footprints. Consequently, conventional 3-D seismic data have only seen very lim-ited use for hazard evaluation in water depths of less than 500 m (1,640 ft).
The dual-sensor GeoStreamer acquisition platform not only facilitates the recording of data rich in both low- and high-frequency information, but importantly it also yields direct access to the various seismic wavefield components that can be uniquely utilized to image the near-surface ge-ology with Separated Wavefield Imaging (SWIM). By de-signing imaging workflows that combine high-resolution 3-D processing with SWIM, very detailed hazard analysis of potential drilling locations can be carried out using ex-isting GeoStreamer data.
Reprocessing to image small structuresSHAZ processing aims to produce high-resolution images of the overburden by processing at a 2 ms sampling rate and on a dense image grid of 6.25 m by 6.25 m (21 ft by 21 ft). The velocity model for the shallow subsurface is built using a robust full waveform inversion workflow enabling detailed velocity estimation to ensure accurate imaging of very small geological structures. Both prima-ries and SWIM (i.e., multiple) volumes are intelligently merged to what can be considered a full wavefield image of the very shallow overburden.
Availability of low frequencies for better resolutionThe bespoke SHAZ workflow results in seismic images characterized by very stable and compact wavelets all the way from 2 Hz to ~225 Hz in both shallow water and medium water depth settings.
The seismic resolution at the high-frequency end of the spectrum achieved with SHAZ processing of GeoStream-er seismic compares favorably with that of dedicated site surveys; however, GeoStreamer SHAZ data tend to be sig-nificantly richer in low frequencies. This additional low-frequency content results in a much shorter wavelet, which improves the spatial resolution of the SHAZ volumes.
The accompanying figure shows an example of the re-sults achieved with GeoStreamer full-wavefield SHAZ processing in relatively shallow waters using an original exploration-style survey that was acquired using very wide spreads of receiver cables and large sail line separation.
Visit PGS booth 1240 to find out more about its shallow hazard capabilities. n
This crossline example from the Barents Sea shows superior resolution with GeoStreamer full-wavefield SHAZ imaging, revealing shallow gas hazards in the area (arrow). (Image courtesy of PGS)
7E&P DAILY NEWS | J U N E 13 , 2 018 | W E D N E S D AY
The Value of Seabed SeismicProcessing and imaging technologies fully exploit the multicomponent properties of OBS data for improved subsurface characterization.
CONTRIBUTED BY WESTERNGECO
Seabed seismic has become the measurement of choice for exploration, development and reservoir monitoring
in many parts of the world. Modern ocean bottom seismic (OBS) acquisition crews record high-quality broadband, wide- or full-azimuth, long-offset data without the acces-sibility limitations of convention streamer acquisition in proximity to oilfield rigs and platforms. The combination of the rapid evolution of node acquisition technology and the entrance of new players into the market makes OBS acquisition more achievable and competitive than ever.
Content-rich OBS dataBesides supporting the generation of better velocity
models and images through enhanced illumination, OBS acquisition delivers more repeatable time-lapse data that improve the reliability of amplitude inversion for inform-ing subsurface characterization. Unlike streamer acquisition, OBS systems record not only compressional (P) but also shear (S) wave data that cannot propagate through water but are becoming increasingly important because S-waves provide undistorted images beneath gas accumulations. This insight enables the interpretation of reservoirs with low P-wave reflectivity, leading to higher reservoir certainty.
The key to fully realizing the value of multicomponent OBS data lies in data processing and imaging technologies that fully exploit their unique properties. For example, con-ventional step-by-step approaches to deghosting and demul-tiple are routinely applied to seabed seismic data. However, techniques based on up-down deconvolution simultaneously
address all free surface effects to bring two major benefits: improved quality and reduced turnaround time.
Shear-wave splittingOne phenomenon that is both a challenge and an op-
portunity is shear-wave splitting. In an anisotropic medium, shear waves split into a faster wave traveling parallel to the direction of fractures and a slower wave traveling orthogo-nal to them. Although this effect must be compensated for to produce representative seismic images, it can be exploited to pinpoint the direction and density of fractures within reservoirs. However, standard shear-wave splitting analysis has been a time-consuming and error-prone exercise, em-ploying a top-down layer-based approach. Recently devel-oped data processing techniques enable more reliable and efficient inversion of splitting intensity interval values.
Earth model buildingThe earth model building workflow is where the highest
value can be extracted from all of the wavefield components recorded by OBS. Using an integrated approach for shal-low-water environments, such as the North Sea, leverages the dispersive nature of the surface waves to create an ac-
curate near-surface model for the compressional and shear-wave velocities (Vp and Vs, respectively). The long-offset full-azimuth OBS dataset is the ideal input for applying full-waveform inversion (FWI) to generate high-resolution velocity updates. Developments to mitigate cycle skipping in FWI and introduce the use of reflections for updating deeper sections have enhanced image quality while reduc-ing turnaround time. Elastic FWI provides Vs updates that drive the next improvement in quality for converted wave (PS) images.
Joint PP and PS tomography, which enables simultaneously updating both Vp and Vs, ensures that a single well-constrained model is produced to explain the entire wavefield. A key part of tomographic updating is the inclusion of event registration constraints via the interpretation of matching events on both the P-wave and S-wave images. Whereas matching event in-terpretation has been an uncertain and lengthy part of the model-building process, a new dynamic warping plug-in for the Petrel E&P software platform automates and improves the robustness of this step, further ensuring better quality models with a faster delivery time.
To learn more about OBS data processing and applica-tions, visit Schlumberger at booth 610. n
#WintershallOnTrack
Visit us at stand #815
A view of the drilling pipe on the Deepsea Stavanger drilling rig, from which the wells for the Maria field were spudded into the depths of the Norwegian Sea.
Shaping the future.
WesternGeco’s joint PP-PS tomography improves velocity modeling efficiency by simultaneously updating Vp, Vs, and the Thomsen sigma parameter. (Image courtesy of WesternGeco)
New for Copenhagen–EAGE Code ShowExhibition, booth 1830
A team of geoscientists will be waiting to show you around, answer your coding questions, and get you started as a computational geoscientist. You’ll be able to see what went on at the Subsurface Hack-athon, with demos from some of the teams. You can try a tutorial or two and find out how coding is evolving—and why geoscientists should care. And we’ll have some projects for you and your friends to hack on. Maybe you’ll come up with a novel new visualization or invent the app that every geoscientist will want!
8 W E D N E S D AY | J U N E 13 , 2 018 | E&P DAILY NEWS
Digitalization Increases Business Value of E&P DataThe digital transformation program is bringing new services and products to the oil and gas industry.CONTRIBUTED BY CGG
There is a lot of buzz around “digitalization.” It is trend-ing on social media and in countless business journals
around the globe. To different people it means a variety of different things, from Big Data to the cloud and the Internet of Things. So what is it, and what does it mean for geo-sciences in the oil and gas industry?
There are numerous definitions around the idea of “the creation of new business insight and business value using data.” However, this is what the upstream industry has been doing for decades: acquiring, processing, analyzing and in-terpreting data to deliver business value. Although much of the data in the oil and gas industry are already digital, it is likely that a large proportion of that data are still somewhat isolated and inaccessible and underused for decision-making. For the industry, perhaps the real challenge and opportunity will be “the creation of new business insight and business value using most, or all, of the data.”
Digitalization will see companies transform more of their data into accessible digital databases/data lakes, which will enable the application of data science on large and diverse datasets. Here data science covers disciplines such as Big Data analytics and machine learning, which are proving so popular in other industries.
CGG is well aware of the challenges of digitalization. As an integrated geoscience company, it has a large library of geophysical and geological data, which it recognized could generate greater value if they were fully digital and accessi-ble. In addition, the company has a full range of software that could take advantage of the new technologies and trends.
As a consequence, it embarked on a digitalization program in 2014.
At that time, considering how to progress presented a con-ceptual, organizational, technical and commercial challenge, and a learning opportunity and experience that was shared by many companies in the industry. Some of the projects addressed the absolute fundamentals of being digitalization-ready, such as having an IT platform that could support Big Data and a common database format that could support a diverse geoscience data lake. Other projects focused on how to deliver the promised business value by developing and
implementing new data mining, artificial intelligence and visualization techniques.
At this year’s EAGE conference, CGG will be showcasing early results from its digitalization program. CGG’s digital transformation efforts include services ranging from media conversion to data remediation and integration using ma-chine learning automation to building consistent geoscience databases that are ready for data science.
The Robertson New Ventures Suite is the first commer-cial result from CGG’s GeoVerse digital transformation pro-gram for geoscience data. Built from the rich and extensive Robertson geologic multiclient library, this family of geosci-ence tools and databases shares a universal data architecture and taxonomy to provide integrated workflows that enhance new ventures and exploration activity. Daily booth theater presentations featuring exploration case studies will demon-strate how the suite can be used to de-risk exploration.
CGG GeoSoftware also is taking advantage of new digital opportunities presented to the industry. The company has enabled its products to run in the cloud and is progressing the benefit of flexibility and compute power scalability that it offers. In addition, the latest release of PowerLog enables users to solve complex petrophysical and reservoir engineer-ing challenges by accessing external machine learning and deep learning Python programs, opening up vast possibili-ties for leveraging open source technology and solutions and designing bespoke workflows. The first commercial Neural Network-based approach for reservoir characterization was released over 20 years ago in HampsonRussell’s Emerge geostatistical attribute prediction module. Innovation con-tinues in the HampsonRussell software with planned release of advanced deep feed forward neural network technology and native Python extensions in 2018.
Visit CGG’s booth 1640 to learn more. n
Machine learning applications for reservoir characterization: (from left to right) the low-frequency inversion starting model, predicted density from inversion using HampsonRussell Strata and the predicted density from HampsonRussell Emerge using deep feed forward neural network analysis. (Image courtesy of CGG GeoSoftware)
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Geoprediction, Google Gateway to AIAI is of little use to geoscientists until it can be incorporated into the workflow in a meaningful way.CONTRIBUTED BY IKON SCIENCE
Artificial intelligence (AI) could be “the next big thing” for geoscience, but it cannot be left solely to the data scientists
because they do not have domain knowledge. What is needed is an AI-friendly platform that is familiar to geoscientists.
For this reason, Google has teamed up with Ikon Science to use its RokDoc platform as a pathway to access machine
learning capabilities. Through RokDoc, Ikon Science offers data loading, qual-
ity control, display (seismic, logs, core data, etc.); data condi-tioning, which is crucial for AI; and physics analyses. Goog-le offers best-in-class AI capabilities and access to Google Cloud Services.
The link between the two is RokDoc’s external interface, which has access to Big Data through many channels, links
RokDoc to Python, the commonly accepted language for AI. The external interface comes preloaded with easy-to-use
AI libraries. These include Scikit-learn (for non-neural net-work methods); Tensorflow (for neural network methods; Google’s flagship product; and Matplotlib (for plotting).
The external interface allows two-way traffic of rock physics models, 1-D profiles, 2-D sections and 3-D volumes.
In fact, Ikon Science has been training users to make AI plug-ins using RokDoc’s external interface since 2017 with-out having to worry about data loading, display, etc.
A booth presentation will give examples of extracting shapes/morphologies from seismic, but in terms of deriving rock properties, seismic does not contain low frequencies. And while AI can do many things, it cannot invent data, for instance, the low-frequency model (LFM) required to invert for rock properties. Why? As in populating the LFM, no AI algorithm knows the exact location and shape of the various facies to post the acoustic impedances of those facies.
This is the reason Ikon Science developed Ji-Fi. Ji-Fi takes in multiple LFMs, one for each facies expected in the subsur-face. Whereas AI cannot create one LFM, it is perfectly con-ceivable that AI could create a LFM as if the entire subsurface is shale or limestone or sand. This results in a powerful com-bination of data science (AI to create the per-facies LFMs) and physics (Ji-Fi taking in the per-facies LFMs to convert the seismic to 3-D images of facies and impedances). n
EAGE Photo ContestA traveling exhibition of the top 12 photos of the EAGE/EFG Photo Contest 2018 themed “Geo-scientists at work” will be displayed during EAGE 2018. Help to select the winning picture in the sec-ond round of voting by casting your vote at prod.eage.org/en/photo-contest. The winner will be an-nounced Oct. 1.
9E&P DAILY NEWS | J U N E 13 , 2 018 | W E D N E S D AY
Making Collaboration a RealityRealistic uncertainty quantifications enable better decisions through accounting for both risk and potential upsides.BY ARNE SKORSTAD, EMERSON AUTOMATION SOLUTIONS
For a long time, a combined workflow from seismic mod-eling (through geomodeling) to reservoir engineering
has been many oil companies’ goal for achieving a unified collaborative reservoir model. Paramount to this goal is that, although the reservoir model is integrated and promotes collaboration, it should not always require all disciplines to work on the same model at the same time. On the contrary, it puts all efforts into a common framework while being flexible and elastic enough to allow different models to be built to support various decisions. This workflow require-ment describes the Roxar Big Loop.
The Big Loop is a philosophy for creating a reservoir model through a workflow linking the static and dynamic domains defined by the user application and data at hand. The workflow supports the propagation of relevant uncer-tainties and dependencies of the data and model parameters to obtain realistic uncertainty quantification. This linking of uncertainties and parameters ensures that reservoir model changes seen as necessary for replicating actual flow data are made under geophysical and/or geological constraints. This makes any update of the reservoir model realistic given all available data but also linked to the geological framework.
Since the uncertainties are propagated from where they are captured to where they matter in the modeling, it fol-lows that the different disciplines involved need to uphold the same understanding of these uncertainties, thereby re-quiring collaboration.
One example of a highly important uncertainty is the depth of the top structure of the reservoir. Uncertainty in the velocity model in particular, but also in the inter-pretation of the reflector, will lead to some uncertainty bound around the base case delivery from the geophysi-cal community.
When the reservoir engineers do history-matching, the dynamic data might suggest a change in this top structure. By not just delivering the most likely top-structure depth but also the actual uncertainty of it given the geophysi-cal model and data, the geophysicist supports the history-matching exercise by narrowing down the search for the most optimal depth given the dynamic data and also ensur-ing geophysically realistic history-match results. In return, the geophysical model also is updated and enhanced, ben-efitting from data and insight from a different domain and from the history-matching on dynamic data.
Putting all tasks in an automated workflow means that contributors must avoid manual edits of the resulting reser-voir model since in general these are nonreproducible, sub-jective and nontransparent. Having a fully automated work-flow enables full reproducibility, meaning that when results are generated all that is needed to recreate results is running the workflow again. Work therefore should be made on the
model parameters and set up rather than the result. This means that all contributing domains have a shared owner-ship of the results, not the individual that chose to make subjective changes to account for a particular data type. A tighter collaboration emerges as a natural consequence.
Since the workflow in both the static and dynamic do-mains are fully automated, the user also can utilize parallel processing capabilities by creating many possible, so-called equiprobable scenarios. By doing so, an ensemble of many possible reservoir models can be created.
Yet which is the right one? The answer is none. All models are approximations of reality and at some
stage will deviate from the truth. It is just a matter of de-tail and time. Having an ensemble of models that honor the data, however, enables users to add to their knowledge the validity of the models by estimating them from the ensemble itself.
With realistic uncertainty quantifications, better decisions can be made through properly accounting for both risk and potential upsides. Then decision makers can make transpar-ent and optimal choices based on quantified estimates of future production estimates—the key benefit of the Big Loop workflow.
For more information, visit Emerson at booth 720. n
Nodal System Delivered to Mitcham IndustriesCollaboration has resulted in small, light system with extended run time.CONTRIBUTED BY INOVA GEOPHYSICAL
INOVA Geophysical has delivered a 5,000-node Quantum system, fully integrated with INOVA’s high-performance
iX1 data management system, to Mitcham Industries, ready for immediate deployment in the Middle East.
INOVA’s continuing collaboration with Innoseis has pro-duced a next-generation nodal system, and with the inte-gration of iX1 and Quantum, INOVA can now offer the industry the smallest and lightest system with the longest run time (50 days at 24 hours) together with a fast, indus-trial-strength downloading and data management system, high-productivity source control and a full range of highly effective quality control (QC) tools. This package offers us-ers improvements in crew costs and operational efficiency without sacrificing data quality or QC capability.
Quantum adds another dimension to INOVA’s broad-band product portfolio, which includes AHV-IV 364, 380 and UNIVIB vibrators, the Vib Pro HD and Shot Pro HD controllers, and the G3i HD land cable system, analog or digital (single sensor) and analog transition zone as well as the HAWK 3-C nodal acquisition system. In partnership with Mitcham, INOVA can now offer a comprehensive selec-tion of products designed to meet any exploration challenge, whether the need is for a low-impact, environmentally sensi-tive nodal and mini-vibe operation or for high-productivity high-density low-frequency desert crews. n
Register now!
Applied Shallow Marine Geophysics Conference
Conference on Geophysics for Mineral Exploration and Mining
European Meeting of Environmental and
Engineering Geophysics
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www.nearsur facegeoscience2018 .org
9 - 13 S E P T E M B E R 2 0 18 P O R T O , P O R T U G A L
20550-COP18 Daily News adverts.indd 2 25/05/18 14:08
The Quantum system is fully integrated with INOVA’s high-performance iX1 data management system. (Image courtesy of INOVA Geophysical)
10 W E D N E S D AY | J U N E 13 , 2 018 | E&P DAILY NEWS
Floorplan exhibition
419 Learning Geoscience Area
EAGE Community Hub
Upload Area & TP Info Desk
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Exhibitors in alphabetical order
Exhibition area
11E&P DAILY NEWS | J U N E 13 , 2 018 | W E D N E S D AY
Floorplan exhibition
419 Learning Geoscience Area
EAGE Community Hub
Upload Area & TP Info Desk
Auditorium 15
To Auditoriums 10 - 12
Bella Sky Hotel
232
420
410
250 Coffee Plaza
421
422424
520
521
522
430
431
300 Associated Societies
to Rooms A-R
MainEntrance
Restaurant / Bar
Toilets
Lift
Escalator
Stairway Emergency ExitCoffee Point
First Aid
Cloakroom
Registration Area
1220
1510
1420
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1430 1530
1445
1550
1620 1720
1630
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16601760
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1415
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to Rooms A-R to Rooms A-R & E-Posters
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DOWNLOAD the EAGE ANNUAL
2018 APP now!You can access the EAGE Annual 2018 App by going to the App Store or Play Store and searching for eventsair. Download The Event App and put in the code: geo2018.
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Gippsland ReGeneration 3D Multi-Client Reprocessing ProjectGippsland Basin
Paul Rheinberg+61 403 462 [email protected]
With over 12,000 km² of legacy 3D seismic already in reprocessing, the Gippsland ReGeneration project is breathing new life into a mature basin. Using the industry’s most advanced imaging tools and methods, such as dispersive groundroll removal, 3D joint source and receiver designature and deghosting, FWI, advanced demultiple techniques and least-squares Q migration, CGG is identifying new drillable prospects.
This high-end reprocessing project is regenerating the Gippsland Basin and will help to address the projected shortfall in Australia’s East Coast gas supplies.
The right data, in the right place, at the right time
Contact us now for further information:
Gippsland legacy data Gippsland reprocessed data
Visit EAGE booth #1640 to learn more.
PRIM
E PRO
SPEC
T
cgg.com/gippsland
18AD-MM-169-V1_Gippsland_EAGESD3_Jun.indd 1 17/05/2018 17:56:35