Reservoir Focus for Giant Offshore Duo - Hart's E&P

OFFICIAL SHOW DAILY PUBLISHER OF THE 75TH EAGE CONFERENCE AND EXHIBITION 

LONDON THURSDAY 

DAILYNEWS 

2013 EAGE Conference & Exhibition 

Reservoir Focus for Giant Offshore Duo 

The benefits of imaging and characterization studies are clear on Kashagan and Lula. 

By Mark Thomas, Senior editor 

Two of the largest offshore fields ever discovered have been in the spotlight at EAGE 

2013, with the ongoing development of both critically influenced by the application 

of reservoir imaging and characterization technologies. 

The two giants concerned are very different animals. One is the huge Lula field 

(formerly called Tupi) in the presalt Santos basin, lying in ultra-deep water and with 

recoverable reserves estimated at around 8 Bbbl of sweet light oil. 

The other could not be more different: the even larger Kashagan light oil and sour 

gas presalt giant in the shallow waters of the northern Caspian Sea, one of the largest 

discoveries made in the last 30 years with recoverable reserves put at up to 13 Bboe out 

of estimated gross reserves of more than 35 Bboe. 

Kashagan is part of the North Caspian Sea production-sharing agreement operated 

by the North Caspian Operating Co., on behalf of a consortium consisting of KazMunayGas, 

Eni, Shell, ExxonMobil, Total, ConocoPhillips, and Inpex. 

Super-giant complex reservoir 

In an Eni presentation during a reservoir simulation session yesterday, the operator 

outlined work by the company and its partners since the field’s discovery in 2000 to investigate 

the reservoir characteristics for this super-giant and complex fractured carbonate 

reservoir offshore Kazakhstan. 

The field covers a surface area of approximately 75 km by 45 km (47 miles by 28 

miles) and sits in water depths of between 3 m and 9 m (10 ft and 30 ft), while the huge 

reservoir itself sits around 4,200 m (13,780 ft) below the seabed. Its challenging technical, 

logistical, and environmental nature means that it has taken some time for the operator 

and its partners to bring the first development phase of the field to fruition. However, 

Kashagan is expected to 

begin flowing first oil and 

gas later this year. 

The first experimental 

program phase will 

see around 180,000 b/d 

produced from the eastern 

part of the field, with the 

production figure only 

constrained by the gashandling 

capacity. The 

overall scheme will see 

production hubs located 

on six platforms and 

artificial island mounds 

(mainly to act as ice barriers), 

collecting production 

from satellite islands from 

where production wells 

are being drilled. 

The FPSO Cidade de Angra dos Reis has been in operation since 

October 2010 on the Lula field, which was chosen as a pilot area for 

a multi-azimuth project. (Image courtesy of Petrobras) 

The first phase’s oil and nonreinjected sour gas will be treated in the hubs and delivered 

through two separate lines to onshore treatment plants near Atyrau. The oil will be 

further stabilized and purified. The gas will be treated for the removal of hydrogen sulfide 

and will be used mostly as fuel for the production plants, with the remaining amount to 

be marketed. 

See GIANT continued on page 6 

4-D Data Add Value to BP’s Greater Plutonio Project 

High-quality seismic data aid operator in optimizing well placement and reservoir management. 

By Mark Thomas, Senior editor 

repeating 4-D seismic program over the large Greater Plutonio development in Angola’s 

A deep waters has provided important subsurface data and significantly aided well placement 

and reservoir management. 

According to operator BP, a baseline survey and two monitors acquired so far (with a 

third planned for this year) have provided long-term value for the development in Block 18 

through better well placement. 

In a conference session at EAGE 2013 yesterday on time-lapse interpretation, BP’s Joe 

Jackson told a packed auditorium that good source and receiver repeatability has been key to 

providing high-quality 4-D images. Improvements in 4-D seismic processing, including multivintage 

parallel workflows, have led to enhanced images for the project. 

Greater Plutonio itself consists of five fields of Oligocene age, in water depths ranging from 

1,200 m to 1,500 m (3,937 ft to 4,921 ft). They are operated by BP, partnered by Sonangol 

Sinopec International (SSI), and on behalf of concessionaire Sonangol. Production began in 

2007 via an FPSO vessel at 120,000 b/d of oil. 

To date the 4-D seismic program consists of the baseline, high-resolution 3-D narrowazimuth 

towed-streamer survey acquired in 2000 and two repeat monitor surveys in 2009 and 

2011. Each survey was processed through both a fast track and a parallel workflow. In the fast 

track workflows datasets were processed separately and matched to the baseline at key stages. 

In the parallel workflows all datasets were simultaneously processed with multivintage techniques 

employed for steps such as binning and destriping of the data. 

Jackson in particular flagged the company’s use of steerable sources and streamers for 

improved 4-D data quality. “Such improvements reduced artifacts, improved 4-D signal, and 

provided greater value from the data,” he said. 

He also gave an example of how the 4-D program led to the retargeting of a well based 

upon evidence from the 4-D data on the Cobalto field, which is part of the Greater Plutonio 

cluster. A planned injector was originally intended to support production from a producer 

well in the north of the field. The 4-D data provided clear evidence that the aquifer is very 

strong in this part of the field and that a dedicated injector was not required. The data also indicated 

that the planned injector well would have accelerated the pace of water influx toward 

the producer well, leading to the injector well being retargeted to another area of the field. 

This, Jackson said, was a direct example of value being gained from the 4-D data. “Attention 

to detail in acquisition and processing has resulted in excellent-quality 4-D data, with the 

resolution to image fluid changes in thin sands,” he said. “The application of 4-D technology 

has significantly improved the understanding of fluid movement within the Greater Plutonio 

reservoirs, and this information has been used to optimize offtake and water injection rates 

and to retarget wells to maximize oil recovery.” Jackson also acknowledged the support of 

PGS and CGG in the acquisition of the baseline and monitor surveys and the latter’s efforts in 

optimizing the processing of the 4-D data. n 

inside this issue 

2 Conference Program 

4 delivering the best multiclient data 

5 A WORLDWIDE LICENSE TO OPERATE 

12 unlocking shale gas and oil resources 

15 delivering your basin in a box 

16 EXHIBITION FLOOR PlAN 

991-994 covers-JUNE_Layout 1 5/20/13 11:06 AM Page 991 

JUNE 2013 

Sand and Proppant/ 

Fluid Management 

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Deepwater Rig 

Advances 

Land Seismic 

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The Official Show 

Daily of EAGE 2013 

Visit Hart Energy at booth 2012 

or 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. 

E&P DAILY NEWS | JUNE 13, 2013 | THURSDAY

Schedule 

of Events 

2 THURSDAY| JUNE 13, 2013 | E&P DAILY NEWS

Conference Highlight – Executive Session 

Challenging Gas Debate Awaits During London Executive Session 

The global gas supply and demand landscape is changing at perhaps an unprecedented 

pace. This is what should make the executive session on June 13 one 

of the highlights at the 75th EAGE Conference and Exhibition in London. The 

session will feature a discussion on the global gas challenge, co-chaired by Linda 

DuCharme, director of gas and power marketing for the Europe/Russia/Caspian 

region for ExxonMobil International, and Andy Hopwood, COO of strategy and 

regions for BP. 

Speaker will include Matthias Bichsel, projects and technology director for Shell; 

Francis Egan, CEO for Cuadrilla; Ibraheem M. Assa’adam, executive director of 

exploration for Saudi Aramco; and Dieter Helm, CBE, professor of energy policy 

at the University of Oxford. 

The session will address two topics: The first will explore supply and demand 

trends and challenges with a focus on Europe, and the second will address the 

impact of unconventional gas resources on the global gas industry. 

The shale gas revolution in North America has triggered a price collapse in the 

US and has impacted energy markets in Europe. In addition, growing competition 

for gas in Europe is displacing oil-indexed gas and helping the evolution of a 

market-based model. Asia looks to remain the fastest growing gas market, with 

demand expected to grow by more than 130% to 2035. 

In the UK domestic gas production has been falling since 2000 and continues to 

decline by about 6% per year, leading to imports of around 45% of today’s UK 

gas demand via pipeline and LNG. This has focused attention on the potential for 

domestic unconventional gas resources, notably reports of the exploration work 

carried out in the Carboniferous shales of the Bowland basin of northwest England. 

Technology questions on shale gas development as well as public concerns 

on the environmental effects will need to be addressed. 

These are just some of the key issues that will make this executive session a rewarding 

experience, where a spirited debate can be expected. 

E&P DAILY NEWS | JUNE 13, 2013 | THURSDAY 

3

Delivering the Best Multiclient Data 

Leveraging advanced acquisition and processing technologies to maximize seismic programs. 

COntributed by WesternGeco 

The WesternGeco multiclient group benefits from access 

to the industry’s most comprehensive range of integrated 

G&G software and advanced seismic acquisition techniques. 

Decisions about where and how to acquire multiclient data 

are driven by detailed analysis of basin prospectivity and the 

particular imaging challenges of targets with the highest 

hydrocarbon potential, as well as by the timing of future 

license rounds. A detailed study was performed with the 

help of PetroMod petroleum systems modeling software 

to evaluate the potential of basins offshore Mozambique, 

which, following many years of civil war and political 

instability, is becoming more open for hydrocarbon exploration. 

More than 55,000 km (34,175 miles) of 2-D seismic 

data were interpreted, and the results were integrated with 

available gravity, well, and other geological data. The study 

evaluated if and how reservoirs may have been charged 

with hydrocarbons, including the source and timing of 

hydrocarbon generation, migration routes, quantities, and 

hydrocarbon type in the subsurface or at surface conditions. 

Significant natural gas discoveries have recently been made 

in the Rovuma basin in the north of the country, and the 

study indicated that hydrocarbon potential extends south to 

the Mozambique basin including the Zambezi delta area, 

which will soon become available for licensing. Following 

the geological study, WesternGeco survey evaluation and 

design specialists developed plans for an efficient and effective 

seismic program. 

Acquisition of more than 31,000 km (19,262 miles) of 

new long-offset, 2-D seismic data covering the majority of 

the offshore territory commenced in April 2013. The survey 

is being acquired in collaboration with the National Petroleum 

Institute of Mozambique (INP) and is fully supported 

by industry prefunding. The data are being acquired using 

the ObliQ sliding-notch broadband acquisition and imaging 

technique, which optimizes the recorded bandwidth of the 

seismic signal enabling more detailed imaging of the subsurface 

and more reliable extraction of rock properties. Two 

vessels, both equipped for onboard processing, have been 

deployed to ensure the data are ready for evaluation in time 

for the license round applications. The long records will 

help evaluate the position and shape of the basement as well 

as the thickness of the sedimentary section. New gravity 

data will become available for integration into the geological 

model. Advanced processing techniques, including depth 

imaging, amplitude-vs.-offset (AVO) analysis, and amplitude-vs.-angle 

(AVA) analysis will help reduce uncertainties 

in interpretation. 

The ObliQ technique was combined with Coil Shooting 

single-vessel, full-azimuth acquisition in a 2012 multiclient 

3-D survey in the Barents Sea Nordkapp basin, covering an 

area of more than 750 sq km (290 sq miles). The Nordkapp 

basin is an intracontinental syn-rift basin containing many 

complex salt structures. The salt is late Carboniferous to 

early Permian in age, with regional extension in the Triassic 

initiating the salt movement and subsequent tectonic phases 

allowing growth and distortion of these diapirs. Further uplift 

and erosion in the Tertiary may have generated salt-related 

traps in the Triassic and Lower Jurassic. These structures 

are notoriously difficult to image with conventional seismic 

techniques due to the generation of strong multiples from 

the seafloor and the top of the shallow salt structures. Seismic 

shadow zones and structures within the salt – possibly 

shale and carbonate rafts and stringers – cause severe diffractions, 

and prospective areas adjacent to the salt have proved 

to be elusive. The Coil Shooting technique acquires data 

using a vessel sailing in a series of overlapping continuously 

linked circles. It is enabled by the Q-Marine point-receiver 

marine seismic system, which accurately controls the depth 

and lateral position of the streamers. A fully braced acoustic 

positioning network provides accurate positioning information 

for all in-sea equipment. Finely sampled point-receiver 

recording and proven noise attenuation methods handle 

crossflow noise without harming signal fidelity. The technique 

has proved successful in imaging complex geological 

situations through better target illumination thanks to 

greater azimuthal coverage and higher signal-to-noise ratios 

than conventional 3-D methods. As for all recent multiclient 

projects, the Nordkapp basin data are being processed using 

state-of-the art demultiple and prestack depth-imaging 

techniques, including reverse time migration (RTM) using 

an anisotropic velocity field. The results have allowed 

mapping of salt walls, overhanging structures, and potential 

traps that have never before been seen in seismic data from 

the region. 

The Coil Shooting method has been extended to deliver 

both full-azimuth data and the very long offsets required 

to illuminate subsalt hydrocarbon plays in deepwater areas 

of the Gulf of Mexico, which often present severe imaging 

challenges related to thick salt bodies with complex morphology. 

The Dual Coil Shooting multivessel full-azimuth 

acquisition technique involves two recording vessels with 

their own sources and two separate source vessels sailing 

in interlinked circles. Since 2010, more than 27,000 sq km 

(10,425 sq miles) have been surveyed using the method in 

the Revolution program of multiclient projects. The datasets 

have been processed using anisotropic RTM schemes appropriate 

for the complex geology and steep dips around 

the subsalt targets. Three-dimensional prestack acoustic full 

waveform inversion has been used to build high-resolution 

velocity models. 

The WesternGeco multiclient group also is taking advantage 

of the IsoMetrix marine isometric seismic technology 

launched during EAGE 2012. It was used for acquisition 

of the 2013 Ice Bear-2 3-D survey in the western Barents 

Sea, which targeted the Jurassic reservoirs already proven 

in neighboring areas and also potential plays in the Triassic 

sequence and in turbidite fan sediments above the Base 

Cretaceous Unconformity. The processing workflow is 

designed to use the acquired broad bandwidth and fine isometric 

spatial sampling to deliver the highest resolution 3-D 

imaging yet achieved in the area. 

For more information about WesternGeco acquisition and 

processing technologies, go to slb.com/multiclient or visit 

booth 930. n

A Worldwide License to Operate 

The world’s largest land seismic company isn’t resting on its laurels. 

BY RHONDA DUEY, EXECUTIVE EDITOR 

Companies are never too large to learn new things. That’s the 

attitude that BGP brings to the EAGE. Despite its stature 

as the world’s largest land seismic company, BGP’s presence 

at EAGE, according to Vice President Zheng Huasheng, is to 

explore new ideas. 

“This is an open window for us to learn more from our 

competitors,” Huasheng said. “It’s important to know each other 

as integrated geophysical service providers.” 

Added Vice President Liu Juxiang, “Our focal point is to show 

and to learn.” 

BGP has plenty to show. It recently completed acquisition 

on its multiclient survey offshore Madagascar, and while results 

are preliminary, data are already indicating interesting structures 

in the region. The survey was acquired in anticipation of an 

upcoming bid round. Huasheng said that the full dataset will be 

available within two to three months. 

It also boasts a considerable amount of high-end technology. 

For instance, its distance-separated simultaneous slip-sweep 

technology is a fast vibroseis technique that uses two or more 

slip-sweep fleets to increase channel count and reduce acquisition 

time. In transition zone (TZ) environments, BGP offers solutions 

including integrated air gun systems, navigation systems, and 

advanced drilling equipment. The company also uses advanced 

techniques for survey design, field data quality control, and integrated 

data processing approaches. 

Its borehole-to-surface time-frequency electromagnetic 

method combines the transient electromagnetic and spectral 

induced polarization techniques in the borehole to determine 

the hydrocarbon-bearing potential of a geological target. The 

method can help reduce the number of wells to be drilled and 

improve success rates by providing a reliable basis for well network 

design. 

BGP’s GeoEast provides a unified data platform, display 

platform, and development platform to support data sharing, 

visualized interaction, and a collaborative mode for processing 

and interpretation. Its flexible, modular, and scalable architecture 

can be customized to a workstation or a PC cluster to meet the 

needs of onsite processing and large processing centers. 

Its applications include land 2-D and 3-D seismic, data 

processing, conventional structural interpretation, 3-D volume 

interpretation, complex low signal-to-noise land data, resolution 

improvement, and 3-D vertical seismic profile data processing 

and interpretation. In addition, the system provides processing 

and interpretation flows for processing multicomponent and 

ocean streamer seismic data. 

These technologies and more are on display at the BGP booth, 

where visitors also can view demonstrations and visit with geological 

and geophysical experts. “We have a lot of friends here,” 

said Juxiang, adding that the company has more than 200 oil 

and gas clients. Those clients are not just impressed with BGP’s 

technology, Huasheng said. “We also strive for operational excellence,” 

he said. “HSE is an important part of our job.” 

In fact, BGP’s Oman Crew 8622A recently set a new record 

of 11 million man-hours without a lost-time incident. 

The company is currently active in most parts of the world 

with a particular focus on East and West Africa as well as the 

Middle East, Latin America, and Southeast Asia. It has conducted 

surveys over unconventional as well as conventional fields, and 

Huasheng said that includes several surveys over unconventional 

fields in China. 

The company also is keeping a watchful eye on the eastern 

Mediterranean, Huasheng said, and Australia is an increasingly 

active area as well. 

Wherever the company operates, he said some “homework” 

is required. “We focus on the client relationship,” he said. “In the 

case of some of the large international oil companies, we provide 

service to them worldwide. That client can bring you anywhere.” 

This, in turn, has given the company a good international 

reputation. “We like to have good cooperation with different oil 

and gas companies,” he said. “It’s a tough job, especially when 

you’re working in the field. We work with the local communities 

to make it a win-win for our clients.” 

Added Juxiang, “We’ve created a lot of working opportunities 

around the world.” 

To learn more, visit BGP at booth 850. n 

Blueback Reservoir 

Releases Updated 

Toolbox 

Blueback Reservoir, a technology company specializing 

in providing Ocean plug-ins and 3-D geomodeling 

services for the global oil and gas E&P industry, has 

released the Blueback Toolbox version 14. 

The Blueback Toolbox suite of Petrel plug-ins contains 

Petrel features not available in standard Petrel. It has been 

developed by the Blueback Reservoir development team 

using the Petrel development framework called Ocean. 

The suite was developed in coordination with the Petrel 

software teams at Schlumberger. 

Split into four different domain modules, the Blueback 

Toolbox is a collection of more than 100 plug-in 

features complementing current Petrel workflows, and 

it has proven to be a valuable time-saving tool for Petrel 

users, according to the company. Version 14 contains 

the “freeze window” tool that prevents common user 

mistakes when creating presentation material and the 

“interactive facies generator,” which is a time-saver when 

doing facies modeling. 

“Our client-driven approach has once again proven to 

be successful. Now anything is possible in Petrel by combining 

our software skills and the user requests,” said Dr. 

Mårten Blixt, product manager at Blueback Reservoir. 

The four modules of Blueback Toolbox are seamlessly 

integrated with Petrel with the same familiar and 

easy-to-use user interface and can be downloaded on 

the Schlumberger Ocean Store (ocean.slb.com). Contact 

Blueback Reservoir for additional information. n

Analyzing Seismic Data Using Interpretation System 

New software includes a toolkit of commercial plug-ins. 

Contributed by dGB Earth Sciences 

Four years since OpendTect became the first seismic interpretation 

system to be released under the GNU GPL 

license and 116,000 downloads later, dGB Earth Sciences is 

launching OpendTect 4.6 at EAGE 2013. The dual-licensing 

model is free under the GNU GPL license and comes with a 

variety of commercial plug-ins under a commercial license. 

OpendTect 4.6 comes with a new plug-in called Synth- 

Rock that combines forward modeling, rock physics, and 

inversion to create a new toolkit for creating and using forward 

models in qualitative and quantitative seismic interpretation 

studies. It is through this forward modeling of synthetic 

seismic data that interpreters are able to separate true hydrocarbon 

anomalies from false positives and make more accurate 

reservoir predictions. 

Quick workflows using simple wedge models and cross 

sections created from interpolated wells (pseudo-wells) can be 

run in “what if” scenarios. In addition, sophisticated workflows, 

where model parameters are varied stochastically, are 

run to create a database of pseudo-wells representative of the 

expected geologic and seismic variations at target level. Such 

models are 

INOVA-0005_Hawk_Ad_EAGE.pdf 

then used to predict rock 

1 

properties 

5/2/13 

with 

1:14 PM 

uncertainties 

from prestack and post-stack seismic volumes. 

Simple wedge models also can be generated to help 

understand the seismic response of the interval of interest, 

and more complex stochastic simulations can open the way 

to advanced reservoir characterization workflows via crossplots, 

PDFs, or an inversion approach called the HitCube. 

With the HitCube, stochastic pseudo-well synthetics are 

matched to measured seismic responses, and seismic inversion 

can take place without known target information and 

the 4-D difference logs. 

SynthRock also makes full use of the seismic interpretation 

system to support a range of modeling and 

inversion workflows. 

Functions that are supported include a profile module for 

the creation of cross sections from existing wells, a stochastic 

module to create stochastically varying pseudo-wells, prestack 

synthetics and the automated update of the synthetics as the 

model is created or updated, a comprehensive rock-physics library, 

interactive scaling of the synthetics to the actual seismic, 

and inversion possibilities such as cross-matching procedures 

to create probability volumes through the HitCube and probability 

density functions derived from cross-plots. 

During the London event dGB will host the Opend- 

Tect Sequence Stratigraphic Interpretation System (SSIS) 

consortium, an ongoing initiative since 2005 to develop 

methods and tools to automate seismic sequence stratigraphic 

interpretation. 

The SSIS consortium is currently sponsored by global operators 

and independents such as Saudi Aramco, Statoil, OMV, 

Marathon Oil, MOL, Roc Oil, and Woodside. The EAGE 

meeting also will include a presentation by BG Group on its 

recent use of HorizonCube, an OpendTect plug-in, in the 

company’s geohazard interpretation activities. 

EAGE 2013 also will see the launch of another OpendTect 

plug-in developed by ARKeX, known as XFIELD. The 

technology will enable interpreters to visualize multiple 2-D 

models within a 3-D environment and rapidly build an integrated, 

geologically consistent interpretation that draws from 

and displays both seismic and potential field data. 

Finally, dGB will take part in a joint presentation with 

the University of Alberta on the historical developments in 

Wheeler diagrams and how the introduction of a fourth 

dimension into sequence stratigraphy – the thickness of an 

interpreted stratigraphic unit – is likely to herald a new development 

in seismic interpretation. The talk, “Developments 

and Future Trends in Wheeler Diagrams,” was scheduled to 

take place during EAGE’s sedimentary basin evolution session 

on June 11. To find out more about dGB and its activities at 

EAGE 2013, visit the company at booth 1114. n 

GIANT continued from page 1 

Second phase ramp-up 

A second phase will see production ramped up to around 

370,000 b/d of oil, with a possible increase to 450,000 b/d. 

When later phases are implemented, Eni estimates Kashagan’s 

peak production plateau could hit 1.5 MM boe/d. 

“Due to the complexity of its geology, the high pressure, 

and the sour content of stored hydrocarbons, not to mention 

the harsh physical environment of the Caspian Sea, the 

characterization and development of this reservoir have represented 

a very challenging task,” Eni’s C. Albertini said. 

Part of the produced gas will be reinjected back into the 

reservoir using a five-spot pattern, initially in the D-island 

wells. As the platform interior shows a single porosity behavior 

and, compared to the rim, can be seen as a homogeneous 

environment, this is the best candidate for gas injection, 

according to Eni. 

“The experimental program will represent a unique 

opportunity to collect data regarding downhole pressure 

trend, allowing to infer intrawell connectivity from the wells 

that have been drilled up until now,” he said. “The entire 

[experimental program] plan consists of 40 wells, relevant to 

five clusters. At the moment 20 wells, belonging to islands 

D and A, are available and deemed capable of sustaining the 

production in the short term, while the remaining will be 

drilled by 2016.” 

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Bi-azimuth benefits for Lula 

Brazil’s Lula field was highlighted by Petrobras in a 

multi-azimuth acquisition processing session yesterday 

for different reasons, with the multi-authored presentation 

focusing on the benefits of a collaborative Petrobras- 

CGGVeritas project to optimize the seismic image of 

Santos basin presalt structures. 

For the study, 200 sq km (77 sq miles) of the Lula field 

were chosen as the pilot area. Because the top-of-salt 

level presents a highly variable topology, the companies 

investigated how its geometry influenced the illumination 

at the base-of-salt level and the consequences on the 

presalt reservoir seismic image. The modeling of three 

narrow-azimuth acquisitions showed highly spatially 

variable illumination at the base-of-salt level. 

By combining two existing datasets in a single processing 

sequence, the companies were able to take advantage 

of having different azimuths of acquisition. 

The paper concluded that the illumination study 

“clearly shows the benefit of imaging Santos basin 

presalt structures with different azimuths.” It went on 

to state that key processing methodologies were identified 

and optimized in order to get full advantage of the 

data integration, such as cold water statics correction for 

compensating variations in the water column and postimaging 

data conditioning for improving the signal-tonoise 

ratio of the final stack image. 

“This bi-azimuth project provides a comprehensive assessment 

of the potential benefits of multi-azimuth data 

that will improve presalt carbonate reservoir imaging. 

The outcome of this evaluation will probably guide the 

decision of acquiring future wide-azimuth data in the 

Santos basin,” the paper said. n 


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The Role of Structural Geology in the Oil and Gas Industry 

Adherence to sound principles was the focus of Geology Society’s November meeting. 

By Dave Quinn, Badley Geoscience Ltd. 

November 2012 saw one of the most well-attended and 

well-received Geology Society of London conferences 

in recent times. The topic was simple: structural geology 

and its role in the petroleum industry. Many of the shining 

lights from the world of structure (Cosgrove, Price, Yielding, 

Jackson, and Walsh, to name but a few) gave insightful 

presentations on how the understanding of one of the 

fundamental aspects of geology has progressed over the 

years. Debates were healthy and heated, but the resounding 

conclusion was that while the application of structural 

geology in the petroleum industry is clearly critical it is all 

too often ignored or poorly executed. 

Why is this? Surely the unchanging principles of displacement 

analysis outlined in Walsh and Watterson 1988 

have filtered into the subconscious of every interpreter 

some 25 years later? Quite the opposite appears to be 

the case. With the advent of auto-tracking and attribute 

(e.g., coherency) volumes it appears geoscientists have 

forgotten that a fault can only mechanically dislocate 

a layer in a physically possible way. Contour clusters at 

fault tips, unrealistic changes in depth, faults artistically 

drawn through where no fault exists: What is the result 

A paper in press is illustrated above. The fault framework on the left was used for 

many years by a major oil company in a producing field. The one on the right has been 

structurally validated. (Image courtesy of Badley Geoscience Ltd.) 

of drilling on the basis of such a map? Missing the crest, 

the interval, a dry hole: all the things that cost companies 

millions and billions and much of the time 

could have been averted by the relatively 

cheap resource of a trained geologist with 

the correct software. 

Too much trust has been handed over 

to software capable of quickly producing 

mechanically impossible models. If your 

workflow does not involve some form of 

structural quality assessment, even if that 

cellular model you struggle to make work 

has been around for years, then you would 

do well to find a single attendee of the 

Geology Society conference in London 

that would say it is okay to blindly press 

ahead in the hope that your model is 

structurally sound. 

Figure 1 shows a paper in press. The fault 

framework on the left is the one that had 

been in use for many years by a major oil 

company in a producing field. The one on 

the right has been structurally validated. It 

does not take an expert to do this. It does 

not even take very long if you have the 

correct software, and it certainly does not take one long 

to see the value in doing it correctly. The principles of 

structural geology are not kept secret, yet time and time 

again they are not adhered to, mistakes are made, and 

targets are missed. n 

Getting More from 

Multisurvey Analysis 

with Geostatistics 

Geovariances, worldwide leader in geostatistics, 

offers a new application in its reference 

geostatistical software solution Isatis for time-lapse 

seismic processing. 

The multiple acquisition automatic factorial 

Kriging (MAAFK) offers an efficient way to extract 

the common features or the differences between 

two seismic vintages by applying geostatistical multivariate 

filtering techniques. 

The application has many uses such as: 

• Time-lapse seismic processing to estimate the 

common velocity cube, to assess measurement repeatability, 

or to enhance the 4-D signature; 

• Data reduction processes such as stacks, amplitude 

vs. offset, and EI to enhance results; and 

• Data merging such as the onboard computer 

and streamer data combination. 

Depending on the task requirement, the information 

to process is contained in the common part as 

with common velocity cube estimation or in the 

residual part as with 4-D signature enhancement. 

Geostatistical filtering techniques are commonly 

applied to remove artifacts like organized noise or 

acquisition imprints in raw dense velocity cubes 

and improve the quality of seismic data such as velocity 

cubes or interpreted horizons where standard 

filtering techniques such as mid- or low-pass filters 

are insufficient. 

MAAFK applies the exclusive-to-Isatis automatic 

variogram fitting algorithm and automatic multivariate 

geostatistical filtering technique through 

factorial cokriging. 

Starting from two gridded datasets, the workflow 

achieves a factorial cokriging and automatically computes 

the common part and the two residuals describing 

the noise and artifacts affecting the acquisitions. 

The process calculates experimental variogram 

maps (cross and simple variogram maps), then fits 

them automatically using the software’s exclusive 

automatic variogram fitting algorithm. To speed up 

computations, variography and factorial cokriging 

use the fast Fourier transform on gridded data. 

Variogram can be adapted at best locally using local 

variogram parameters to account for nonstationary 

components such as vertically-varying noise. 

For more information, visit Geovariances at 

booth 124. n 


RIGHTBAND 

TM 

Optimizing 3D seismic imaging. 

Intelligent project design 

Broadening the frequency content of seismic datasets 

has recently become an essential technique for improving 

image quality and attribute extraction. Early solutions were 

highly engineered. Modern holistic solutions such as those 

offered by Polarcus can now deliver equivalent or better 

results. At the core of the Polarcus approach is our 

belief in the intelligent application of geophysical principles, 

involving each component of the seismic workflow. 

It is widely recognized today that a high signal-to-noise 

ratio is the key defining element. Our custom-designed 

source arrays generate broadband signals tailored for 

the specific geological objectives of each project. Our low 

noise 2Hz true-solid streamers, deep-towed and recording 

in the ultra-silent environment created by our X-BOW 

vessel hulls, deliver optimized data with the lowest possible 

noise content across the entire frequency spectrum. Other 

benefits of this low noise environment include extended 

weather windows for acquisition and an optimized 

signal-to-noise ratio over the whole desired frequency 

spectrum, especially at the low end. 

No magic black boxes or complex towing configurations 

needed. Just intelligent choices to deliver optimized 

high signal-to-noise ratio data to the data processing 

specialists. 

For the highest quality broadband imaging, advanced 

processing methods are required to complement our 

optimized acquisition techniques. Our preferred solution is 

ION GX Technology’s WiBand. The resulting combination 

of optimally-acquired seismic data and advanced data 

processing techniques enables us to deliver the highest 

quality 3D RIGHTBAND images, tailored to meet the 

specific objectives of each survey. 

For more information talk to one of our local representatives 

or email us at rightband@polarcus.com. 

Conventional seismic data 

Data courtesy of Ophir Energy. 

RIGHTBAND data processed using ION GXT’s WiBand 

Making the RIGHTCHOICES TM 

Visit us at booth #550

Modeling Solution Selected 

SCDM Energie selects Paradigm for petrophysical analysis and reservoir modeling. 

COntributed by paradigm 

Paradigm announced that SCDM Energie has adopted 

the SKUA subsurface product suite and the Geolog 

formation evaluation solution as its corporate standards 

for reservoir modeling and petrophysical analysis. The 

announcement was made at the 75th European Association 

of Geoscientists and Engineers (EAGE) conference 

in London. 

The SKUA suite of subsurface modeling applications 

provides users with the next-generation software 

they need to create more accurate, unbiased, 

and geologically realistic 3-D structural, velocity, and 

reservoir models. 

Geolog 7, the latest version of the company’s formation 

evaluation system, combines its best-in-class 

Deepwater Intl E&P size_Layout 1 5/20/13 9:12 AM Page 1 

petrophysical and geological analysis solutions, well 

data management, and robust data integration with 

a modern, user-friendly interface that is consistent 

across multiple platforms. 

“Among all the available products on the market, 

we selected Geolog and SKUA solutions to meet 

our operational requirements,” Bernard Vigneaux, 

exploration manager at SCDM Energie, said. “An 

advanced software portfolio, transparency, ease of 

use for both junior 

and senior analysts, 

and great flexibility 

were our priorities. 

These capabilities 

together with Paradigm’s 

highly responsive 

local support and 

maintenance were the 

deciding factors in 

our decision.” 

“Upstream oil and 

gas companies continue 

to see value in the 

ability of our products 

to manage data 

in complex wells and 

create 3-D models of 

Accurate 3-D structural and reservoir models of a complex field with SKUA are shown. the subsurface with 

(Image courtesy of Paradigm) 

multiuser capabilities,” 

said Emmanuel 

Gringarten, solution manager for reservoir modeling 

and engineering at Paradigm. “The greater accuracy 

of our results delivers more information from our 

customers’ data and ultimately provides them with 

greater confidence in their drilling decisions.” 

To learn more, visit pdgm.com. n 

Western Australia Opens 

Areas For Exploration 

Western Australia’s petroleum sector has been 

given a boost, with the Department of Mines 

and Petroleum (DMP) opening up six different areas 

across the Midwest, Pilbara, and Eucla for exploration, 

a news release from the government agency said. 

DMP Petroleum Executive Director Bill Tinapple 

said the department’s latest acreage release included a 

mixture of highly prospective and greenfield areas. 

“One release area is located east of Geraldton in the 

Perth basin, which is known for oil and gas production 

and excellent infrastructure,” Tinapple said. 

An additional two areas are situated off the Pilbara 

coast within the highly prospective Northern Carnarvon 

basin, which produces more petroleum than 

any other Australian basin. 

“We’re also offering an under-explored area south 

of Exmouth in the Southern Carnarvon basin, as well 

as two larger release areas in the Officer basin, located 

in the central eastern part of the State,” Tinapple said. 

Work program bids for the release areas close at 4 

p.m. Nov. 14, 2013. n 

Licensing Round Awards 

Announced 

T 

he Ministry of Petroleum and Energy today announced 

the award of new licenses in the 22nd Licensing Round 

on the Norwegian Continental Shelf. Based on these 

awards, EMGS expects to realize uplift revenues of approximately 

US $9 million from data-licensing agreements related 

to the company’s multiclient library in the Barents Sea. 

The uplift revenues are subject to EMGS customers’ formal 

approval of the awards offered by the Ministry of Petroleum 

and Energy. n 

E&P magazine and Deepwater International join with SEN 

Bringing you more offshore news 

and analysis than ever 

With the 2012 purchase of Deepwater International and its justannounced 

acquisition of Subsea Engineering News (SEN), 

now Hart Energy and E&P offer more in-depth coverage of offshore 

exploration and drilling. Our subscribers gain access to more than 

1,800 technical articles, news items and in-depth analysis features 

each year! 

Did you know E&P was created in 1998? That’s when we combined 

Petroleum Engineer International (PEI), Euroil and Hart’s Oil & Gas 

World? Then 75 years old, PEI had covered offshore activity since the 

very first offshore well, and Euroil was an early leader for its in-depth 

coverage of the North Sea. 

That means our editorial teams have covered this critical industry 

sector longer than any other so-called “offshore” publications. 

The addition of Deepwater International and Subsea Engineering 

News (SEN), two highly regarded technical newsletters, simply 

strengthens our franchise – and improves your access to detailed 

business information. 

While at EAGE, stop by the Hart Energy booth (#2012) and request your 

free E&P subscription. See for yourself how deeply committed we 

are to continually providing more (and better) actionable intelligence 

to offshore professionals. 

E&P magazine is the industry's leading publication covering worldwide exploration, drilling 

and production operations, both onshore and offshore. For more information, visit EPmag.com. 


Broadband Digital Sensor 

The Lightest System For High Density Surveys 

Exceeding today’s highest channel requirements 

and delivering the best signal, 428XL, with DSU1 is 

the most effi cient system. 

BROADBAND SIGNAL 

0 - 800 Hz linear response 

Ahead of the Curve SM 

IMPROVED PRODUCTIVITY 

Paving the way to 1,000,000-channel acquisition 

SIMPLIFIED OPERATIONS 

The lightest acquisition system using the fewest cables 

Nantes, France 

sales.nantes@sercel.com 

Houston, USA 

sales.houston@sercel.com 

www.sercel.com 

Visit Us at Booth 

520 

A NYWHERE. A NYTIME. E VERYTIME.

Supporting TPDC with Deepwater License Round 

ION is working to help oil and gas companies understand East Africa’s potential petroleum systems. 

COntributed by ion geophysical 

Recent discoveries offshore Tanzania and Mozambique 

highlight East Africa as an emerging world-class petroleum 

province. Oil and gas recoverable reserve estimates for this 

province total 12.5 Bbbl and 250 Tcf of gas, according to US 

Geological Survey assessment Brownfield et al, 2012. These 

estimates would appear to underestimate the ultimate potential 

of the area given the magnitude of recent discoveries. In 

addition, the activity and analysis in producing areas on the 

conjugate margin are spurring renewed exploration interest. 

Tanzania will open its fourth deepwater license round in 

Dar Es Salaam Oct. 25, 2013. The Tanzania Petroleum Development 

Corp. (TPDC) will offer nine deepwater blocks 

covering more than 6,577 sq km (2,539 sq miles). ION Geophysical’s 

GeoVentures group is working directly with the 

TPDC to provide technical support in evaluating the offshore 

areas and their prospectivity. 

As part of this evaluation, ION has acquired, processed, 

and interpreted approximately 30,000 km (18,641 miles) of 

regional 2-D seismic data offshore Africa’s east coast. Known 

as East AfricaSPAN, this program is focused on the integration 

of offshore margins of Mozambique, Tanzania, and 

Kenya. ION acquired these data with the intent to develop 

DECISIONSPACE 

Well plans well planned. 

© 2013 Halliburton. All rights reserved. 

Offshore Tanzania license blocks are shown in yellow, and the ION 

East Africa SPAN data coverage is indicated by yellow and black 

lines. (Image courtesy of ION) 

DecisionSpace ® Well Planning software 

incorporates your uncertainties, constraints 

and geological data, making your well 

planning decisions faster and more 

accurate. It automatically generates the 

best drilling targets, well paths, field 

layouts and pad positions in a fraction of 

the time. That’s the ingenuity of well plans 

that are well planned. 

Visit www.landmarksoftware.com 

a regional context to evaluate the entire margin and help oil 

and gas companies understand the various aspects of potential 

petroleum systems along this and the conjugate margins of 

Madagascar and West India. The Tanzania data were acquired 

in cooperation with TPDC to enable both TPDC and operators 

to perform a thorough assessment of the deepwater 

potential in this area. 

ION has worked with TPDC to develop the framework 

for an evaluation of known and potential petroleum systems 

in the basin. This technical work underpins the bid round 

data package that will be provided to all oil companies 

interested in bidding in this license round. The data package 

contains information from historical sources and also new 

interpretation and evaluation from the East Africa regional 

interpretation team and outside vendors. The package identifies 

potential play types present in deep water, a summary of 

basin modeling results, and crustal thickness modeling using 

gravity inversion and includes a detailed ArcGIS project containing 

links to all legacy data and studies. The data package 

was designed to allow E&P operators to quickly evaluate the 

license round blocks and high-grade a lead portfolio within 

the context of the entire East African margin. 

ION is continuing to provide bid round support by helping 

to promote the license round, market the data, provide 

data room access, and discuss interpretation of potential play 

concepts. To learn more about the company’s geophysical and 

geological evaluation and/or about the Tanzania bid round, 

visit ION at booth 630 for passes to a technical presentation 

on East Africa to take place Thursday, June 13. n 

Unlocking Shale Gas 

and Oil Resources 

COntributed by SGS Horizon 

The evaluation and modeling workflows for oil and 

gas shales integrate high-resolution seismic inversion, 

petrophysics, petrography, geochemistry, and geomechanics 

to assess the resource potential, plan well completions and 

stimulation programs, and perform production forecasts. 

All work steps require physical and chemical properties 

of the shales as input. For conventional reservoirs such as 

sandstones and carbonates, experiences with respect to rock 

physics and chemistry as well as facies heterogeneities exist. 

In contrast, there is limited knowledge of lithological and 

physical heterogeneities in shales because limited sample 

material from shales was acquired and analyzed. In the past, 

shale analyses were restricted to geochemical and maturation 

analyses to determine the source rock potential. 

SGS Horizon developed a shale gas/oil evaluation workflow 

that incorporates a detailed lithological characterization 

of the shales based on mineralogy, textural, geochemical, 

and geomechanical properties. The company performs 

mineralogical, geomechanical, and geochemical laboratory 

analyses on small-size cutting material (0.063 mm to 0.8 

mm) and developed robust technologies for the vertical and 

lateral upscaling of the cutting analysis results. 

The company applies QEMSCAN technology for the 

mineralogical and lithological analyses of the cuttings and 

a high-resolution CT scan for the detection of texture and 

fractures in the shale fragments. Total organic carbon analyses 

and maturity evaluation from rock evaluation measurements 

provide the geochemical input parameters. Young’s 

modulus and Poisson’s ratio are measured to calculate the 

brittleness/ductility of the shale and determine the seismic 

elasticity parameters for the seismic inversion modeling. 

The cutting analysis data are correlated with mud and gas 

logs and wireline data. Lithology and mineral models are 

developed as input for the seismic inversion modeling and 

the wireline log interpretation. Based on the log interpretation 

and seismic inversion, a gas/oil shale distribution 

(facies) model is established, which captures the vertical and 

lateral shale heterogeneities and helps to identify sweet spots. 

The results from the shale characterization also are used to 

identify appropriate analogues of producing gas shales, which 

can be used as input for the well production forecasts. 

SGS Horizon is member of the KAPPA Unconventional 

Reservoir Consortium and applies KAPPA’s software 

development in the course of the dynamic well data analysis 

and production forecast in shale gas and coalbed methane 

plays. The geomechanical and fracture properties derived 

from the shale cutting sample analysis are applied in well 

and completion planning as well as in the optimization of 

the well stimulation program. n 


Sharing E&P Knowledge Across Multiple Disciplines 

Data management system can help streamline and optimize workflows across the asset life cycle. 

COntributed by schlumberger 

Cooperation Agreement 

Between EMGS and TGS 

Electromagnetic Geoservices ASA (EMGS) and TGS 

signed a cooperation agreement to develop joint 

multiclient projects in defined areas of northwestern 

Europe. With this agreement EMGS will be given access 

to TGS’s 2-D seismic data as the basis for planning new 

3-D controlled-source electromagnetic (CSEM) projects, 

while TGS obtains access to 2-D and 3-D CSEM data to 

design and acquire new 3-D seismic projects. 

“This agreement underpins our strategy to integrate 

3-D EM data with seismic data in the exploration 

workflow and provides further evidence of increased 

industry recognition of our technology. We look 

forward to developing projects with TGS and expanding 

our multiclient footprint,” Roar Bekker, CEO of 

EMGS, said. n 

The Studio environment provides project awareness and access in 

workflow context. (Image courtesy of Schlumberger) 

Productivity is essential in today’s increasingly demanding 

E&P landscape. The industry faces the task of exploiting 

more and more challenging reservoirs with a shortage of 

experienced industry professionals. This requires consistent 

integration and collaboration across multiple disciplines 

as well as a modern and efficient approach to knowledge 

sharing and preservation. 

The Studio E&P knowledge environment can allow geoscientists 

and engineers to streamline and optimize their workflows 

across the asset life cycle while also capturing vital knowledge to 

maximize personal and team productivity. The environment can 

allow geoscientists and engineers to find relevant data, collaborate 

with peers, and capture and share best practices in the context 

of their current workflow. Asset team knowledge can be easily 

accessed by current and future team members. 

Users can access their entire data environment from within a 

project. Indexing technology provides access to both structured 

and unstructured data in the environment’s repositories as well as 

third-party applications and data sources. Search tools can enable 

results filtering based on data-specific criteria. Integration with 

web map services – Esri ArcGIS, OpenGIS standards, and Microsoft 

Bing – can allow users to integrate spatial information. 

The software supports collaboration along multiple dimensions, 

which can allow teams to use instant messaging for 

connecting and communicating with fellow team members 

and session sharing with experts and peers. The knowledge 

environment also can allow teams to add knowledge such as 

notes or analogues to data. It embeds enterprise technology from 

Microsoft Lync, SharePoint, Exchange, and Office, supported by 

the industry-standard enterprise database deployed on Oracle or 

Microsoft SQL Server. 

Integrated workflows delivered by the environment within 

the Petrel E&P software platform can allow users to easily find 

all available information in context regardless of type or location. 

For example, intelligence can be sourced from other projects and 

repositories, and legacy data can be sourced from GeoFrame reservoir 

characterization software, the wellbore software platform, 

and IHS databases. Users can load data into the current project. 

Users can evaluate multiple interpretation or modeling concepts 

and publish results to the team when they are ready; team 

members subscribe to receive notifications of changes and updates. 

The environment allows team members to annotate project 

windows, adding text, documents, images, and video. Users also 

can add quality tag interpretations to highlight confidence level 

and depth of analysis and can embed context and calculations to 

show how particular interpretation decisions were made. 

The environment helps capture and retain knowledge with 

its scalable database so that nothing is lost for future teams and 

new staff members. In addition, the Studio Advisor plugin offers 

tutorials and workflows to maintain productivity. Users can 

benefit from video guides, training materials, methodologies, 

and quality checks. 

Studio Manager allows data managers to track asset team progress 

and resolve data issues by working interactively with users 

of the E&P software platform. Data managers can manage data 

quality and database integrity while at the same time seeing how 

asset team members are using and sharing technical information. 

The integrated data management environment introduces specifically 

designed apps to administer, browse, correct, and organize 

E&P data. Data managers can quickly evaluate the state of their 

environment, determine the status of various repositories, review 

recent user activity, and identify and complete data management 

tasks. The system also delivers awareness tools to manage 

asset team data, including 2-D and 3-D viewers to see data in 

project context. 

Administrators can configure quality attribute tags, including 

application rules for users, to help users track data quality, state, 

and interpretation context. 

The environment provides tools that enable data managers to 

identify issues or inconsistencies and easily correct them. Information 

relating to global well logs in a specific repository can be 

viewed, filtered, organized, and modified, allowing users to identify 

errors, duplications, and other data problems and determine 

how to correct them using the new user attributes app. 

The environment can enhance productivity and streamline 

interpretation processes in everyday workflows. Information 

management professionals can administer the E&P knowledge 

environment using a modern suite of tools that effectively supports 

core data-management workflows and consolidated user 

and data administration – empowering them to improve their 

teams’ productivity. 

The ability to capture knowledge – and easily work together 

to solve problems and create new knowledge – is essential in 

tackling today’s complex reservoirs. Retaining that knowledge 

and making it available to people across the organization in the 

context of specific analyses is crucial for organizational productivity. 

The integrated data management environment is designed 

to help E&P organizations achieve the necessary efficiencies to 

continue to excel in a rapidly evolving business and technical 

environment. It can enable geoscientists and engineers to find 

information, collaborate with peers, and manage knowledge in 

the context of their workflows to maximize productivity and 

improve decision-making. 

For more information, visit Schlumberger at booth 930. n 

We're now expanding our UK based 

Sales and Multi Client teams 

Visit us at booth # 550 

Apply online 


13

Cableless Recording in Any Environment 

High-bandwidth system enables real-time seismic recording. 

COntributed by Iseis 

The use of cableless seismic recording equipment is now well 

established in the minds of most acquisition contractors 

and oil companies. These instruments come in two flavors: 

those that offer no means of communication between 

ground units and a central system, and those that include 

some form of wireless technology to support at least a minimal 

two-way link. 

The former variety, often referred to as “shoot blind” systems, 

have their fans, many of whom are in North America 

as the uptake of such technology has been more limited in 

most other places. The reason for this restricted acceptance is 

that users elsewhere seem more concerned that lack of any 

ability to remotely monitor deployed ground equipment 

puts hardware, including ground units and batteries, at risk of 

theft. Then data quality may suffer from unacceptable levels 

of noise or from unpowered boxes. With various reports of 

serious shoot blind equipment losses and, in some cases, poor 

levels of recorded data quality, these fears can be well founded. 

However, those systems that claim not to be shoot blind 

systems also tend not to go into detail about the limitations of 

their communications features. They may only mention that 

there is some real-time ability and leave the rest to the reader’s 

imagination. After all, when it comes to cableless recorders, 

what does “real time” actually mean? 

Is the definition the same as that which we have come to 

accept with cabled systems, where, no matter in what environment 

the hardware is deployed, every bit of data including the 

complete seismic file and all health, quality control, and status 

information is transmitted without any meaningful delay? The 

answer is probably no, simply because the radio band that this 

seismic wireless hardware is allowed to use relies on low-power 

2.4 GHz transmissions, which are readily absorbed by water 

molecules, whether in the local atmosphere or in vegetation 

on the active spread. Thus, “long range,” “high bandwidth,” and 

“simple to deploy” often are all mutually exclusive phrases unless 

the operational environment is one of desert-like simplicity, 

i.e. with flat land, low humidity, little vegetation, and trace 

interval just right for the equipment in question. 

One may even see cableless systems refer to their real-time 

ability, implying that all data can be acquired remotely. These 

systems then go on to describe how it is necessary to use a 

2.4 GHz-based harvesting technique to gather data from the 

deployed equipment as an additional stage of operations. Some 

may think it is either real time or it is not. If 2.4-GHz radio 

caused problems when it came to offering any real-time capability, 

then how well can it work in all environments when it 

comes to harvesting? These are some of the issues of which potential 

customers for cableless equipment are becoming aware. 

However, the Sigma cableless continuous record seismic 

system developed by iSeis in Ponca City, Okla., recognizes the 

limitations that laws of physics place on wireless recording. 

The basic Sigma recorder, since its introduction four years ago, 

has offered a communication capability that has proven itself 

in both simple terrain and the toughest of seismic environments 

including jungles, through villages and cities, and across 

difficult water courses. The system uses two-way communication 

technology based on mesh radio networking, making it 

easy to deploy and remotely control and requiring little more 

than putting the seismic box on the ground and plugging in a 

motorcycle or comparable battery. 

The Sigma and hyMesh cableless acquisition system offers high bandwidth. 

(Image courtesy of iSeis) 

There is no need to bury the system to hide it from thieves 

or to leave it switched on at all times, making risky and expensive 

lithium batteries necessary. Each box just communicates 

with its nearest neighbors whether they be north or south, 

east or west, which all in turn communicate with their nearest 

neighbors, forming a two-way mesh of communication paths 

all the way back to the central system. And in the event that all 

paths are simultaneously blocked, Sigma has many gigabytes of 

onboard memory allowing recording to continue while at least 

one communication path is reestablished. 

This method of communication uses little battery energy, 

and iSeis has yet to find a seismic environment where it has 

not worked. But the system does not attempt to offer enough 

bandwidth to send all seismic data to the observer. If it attempted 

such high data rates in areas such as the rainforest or 

population centers, just like with any other 2.4-GHz technology 

it would have great difficulty in working and would not be 

simple to deploy. The system does transmit everything else one 

would expect from a cable system in real-time mode, including 

sensor and battery testing, GPS reception, security status, box 

deployment status, and system health. 

Using the mesh radio networking capability, no one ever 

needs to shoot blind no matter where they want to work. As 

with other cableless systems, as data must still be collected from 

the ground units, Sigma provides multiple ways of harvesting, 

some of which do not rely on 2.4 GHz at all and none of 

which requires ground units to be collected or the recording 

process to be halted. Bird dogs tend to use the USB memorybased 

harvesting for access to all the seismic data for advanced 

quality control testing on the actual seismic file without any 

halt to production. 

For those who want the same high-bandwidth, real-time 

ability expected from a cable instrument, the cableless system 

offers the option of adding mesh-based WiFi technology, called 

hyMesh, to the ground unit. An external plug-in unit, the technology 

combines WiFi and the system’s mesh radio networking 

to enable full data rate capability in tough locations where 

other forms of communication may fail. The plug-in can be 

added to some or all of the system boxes, and by choice of 

appropriate configuration, there is virtually no limit to channel 

capacity and range. The plug-in has the coverage to reach all of 

the system’s boxes within a spread, and its units consist of an integrated 

lightweight pole that can be deployed within seconds 

by the same crew installing the boxes. Sigma now offers high 

bandwidth capability as well. To learn more about the technology, 

visit iSeis at booth 802. n 

New Deployment Strategy 

Service provides longer-term retrievable borehole acquisition. 

contributed by ESG 

Built on ESG’s experience in downhole microseismic monitoring 

solutions, the company unveiled a new deployment 

strategy that can provide longer term retrievable borehole acquisition 

at a lower cost than traditional wireline-based acquisition 

equipment. First used by a microseismic research consortium in 

western Canada, the SuperCable retrievable deployment strategy 

records microseismicity in a producing field more than nine 

months after it was originally installed. The deployment service 

also has been successfully employed to monitor LNG storage 

within a salt cavern in the southeastern US as well as a fireflood 

stimulation in western Canada. 

For short duration projects such as hydraulic fracture stimulations, 

wireline deployment is the accepted method for temporary 

downhole microseismic monitoring. Unfortunately, conventional 

wireline tools typically are not designed for extended deployment 

periods. As a result, the equipment becomes too costly over 

longer durations. 

For long-term reservoir monitoring many operators choose to 

deploy permanent systems, for which ESG has manufactured and 

installed proprietary instrumentation for more than 15 years. Permanent 

microseismic arrays are typically installed in monitoring 

wells using production tubing and are cemented in place to ensure 

good coupling to the wellbore. The retrievable deployment 

service represents a monitoring solution that offers the flexibility 

of temporary wireline deployment with the performance and 

cost benefit of long-term monitoring systems. 

Developed, tested, and commercialized by ESG’s R&D division, 

the SuperCable is a retrievable, multiuse recording system 

designed to break the trade-off between wireline-based monitoring 

projects and permanent installations. The system combines 

ESG’s instrumentation that has traditionally been used to detect 

induced seismicity in permanent reservoir monitoring applications 

with a method that mimics wireline deployment. In its 

inaugural application a 12-level array of 15-Hz geophones was 

deployed in summer 2012 to a depth of nearly 2 km (1 mile) to 

monitor two 12-stage horizontal hydraulic fracture stimulations 

in real time. Microseismic monitoring is used during hydraulic 

fracture stimulations to visualize and track fracture growth in 

an effort to improve the process while detecting any fractures 

that occur outside of the zone of interest. In traditional wireline 

deployment, arrays are typically removed from monitoring wells 

immediately following stimulation of the final stage. Taking advantage 

of the longevity of the SuperCable deployment, the array 

remains installed at the site to listen for seismic activity within the 

reservoir during production operations and will continue until 

the unit is decommissioned in July 2013. 

In addition to hydraulic fracture stimulations, the retrievable 

deployment method can be used for monitoring projects spanning 

a few months to a year, including underground natural gas 

storage, CO 2 sequestration, and thermal recovery operations. In 

these and other environmentally sensitive applications, evaluating 

seismicity in and around the reservoir can provide insight 

into the integrity of production casing and any overlying cap 

rock during injection operations. This insight can provide an 

opportunity for advanced warning of failures that may compromise 

containment. n 

The SuperCable retrievable 

longer term 

acquisition service 

was used to deploy 

a downhole 12-level 

array of geophones 

that detected microseismic 

events. (Image 

courtesy of ESG) 

How EAGE Can Help 

with the European 

Geologist Title 

AGE has become the first official continuing profes- 

development (CPD) provider for the “European 

Esional 

Geologist” title. The title of European Geologist is a 

professional accreditation established by the European 

Federation of Geologists (EFG) and recognizes the 

ability to deliver a high quality of services within the 

practice of geology. 

Those who hold the title of European Geologist 

have achieved suitable academic training and a level of 

professional experience, skill, and competence to perform 

tasks within their professional practice. The title 

also means that the geosciences professional undertakes 

continuing education and training, demonstrating a 

commitment to stay up to date and informed within 

the sphere of their professional work. 

The title is recognizable in all European countries 

and so acts as a passport to professional practice in 

Europe, thereby encouraging free movement of professionals. 

An application for the European Geologist title must 

be submitted through one of EFG’s licensed bodies, 

which are authorized to award the title. In order to obtain 

and maintain the accreditation, title holders must 

provide a record of CPD activities carried out. 

Based on the agreement signed between EAGE and 

EFG in March 2013, EAGE is the first official CPD 

point provider. What this means is that almost every 

EAGE activity in which attendees participate has a 

value and can help maintain one’s European Geologist 

title. For example, CPD points can be obtained when 

guests enhance and maintain skills and knowledge at 

EAGE events and activities such as short courses and 

conferences and when they participate in the geoscience 

community or contribute to CPD as a committee 

member or an instructor/lecturer of activities. n 


Delivering Your Basin in a Box 

Using potential fields geophysics to peel back the layers. 

COntributed by CGG 

If you have ever struggled to understand the complexities of the 

subsurface within the confines of your workstation monitor, you 

will find something far more satisfying to help in your comprehension 

of the matter at the CGG booth: a 3-D printed Earth model. 

Behind this novel deliverable there is, of course, a bigger story. As 

well as highlighting the passion for innovation shared by CGG and 

the soon-to-join Airborne interpretation group from Fugro, the 

model showcases the important role that nonseismic geophysics 

can play in hydrocarbon exploration. 

The featured model is of the King Sound area of the Canning 

basin – an area with huge shale gas potential in Western Australia. 

In this area with limited 2-D seismic coverage, a high-resolution 

airborne gravity gradiometry and magnetic survey was conducted 

to facilitate a 3-D interpretation of the sedimentary structure and 

basement architecture. 

The Airborne interpretation team performed a detailed interpretation 

of magnetic and FALCON gravity gradiometry potential 

field data constrained by the sparse 2-D seismic and well data. 

FALCON data are ideal for high-end earth modeling applications 

as the gravity gradiometry system is the only one specifically 

designed for airborne use and has the highest resolution and lowest 

noise of any such system. 

The main features of interest in the King Sound area were 

high-density Fairfield Group carbonate reef buildups; associated 

fore-reef debris and carbonate clastics; and low-density turbidites, 

debris flows, and associated clastic basinal sequences. Depth slices of 

gravity gradiometer data indicated the distribution of the carbonate 

buildups, the main faults, and the highly channelized nature of 

low-density turbidite flows. The magnetic data complemented this 

with information on the basement architecture and distribution of 

intrusive bodies, which were emplaced within the basin fill. 

Starting with the geological framework for King Sound based 

on the interpreted geological interfaces and faults that honored all 

the available data, the construction of a 3-D earth model began. 

A basement surface and geobodies defining the main lithological 

groups (carbonate sequences, basinal clastics, and intrusives) were 

sequentially added. The model was then further refined via a 3-D 

inversion of the model’s density using the gravity gradiometry data. 

The result was a detailed 3-D earth model delivered rapidly 

and in a cost-effective manner that integrated all available geophysical 

and geological data to highlight the distribution of the 

prospective lithologies. 

This case study is just one example of the value of information 

from potential field data when they are interpreted in an integrated 

fashion. In this case the data were from a frontier exploration 

setting, but they are equally valuable in a range of geological 

scenarios where seismic alone cannot unravel the complexities of 

the subsurface. 

CGG has gained potential field geophysics expertise as a result 

of the Fugro Geoscience division acquisition. The company’s new 

GravMag Solutions group is a leading provider of gravity and magnetics 

services, potential field interpretation software, and multiclient 

data in the industry. It is the combined expertise of these teams 

that makes the joint interpretation of these datasets with seismic, 

well log, and geological data such a powerful tool for hydrocarbon 

exploration in frontier areas and for mineral development surveys. 

Karpinsky Oil and Gas 

Announces License Sale 

Karpinsky Oil and Gas Co. AS (KOGC) has announced the 

sale of two exploration and production licenses in Southern 

Russia. The licenses lie in the hydrocarbon-bearing Karpinsky 

Ridge Oil and Gas trend in the Rostov District and cover an 

area of 4,958 sq km (1,914 sq miles). 

Early 2-D seismic indicates a number of strong drilling prospects 

within the license blocks, meaning there are opportunities 

for expanding the number of prospects in the future. 

“We are extremely excited about this opportunity and 

are looking forward to working with new partners to develop 

this area,” Tom Haugen, KOGC chairman, said. “It is 

hoped that by working together many more opportunities 

will become available.” 

KOGC, the majority shareholder in CJSC Rostneftegaz 

Geo, which holds 100% of both licenses, is selling a minimum 

10% stake. 

KOGC plans to use the equity to finance its ongoing exploration 

and drilling program, including the completion of wells 

in both the Gashunsky and North Donskoy license blocks. 

AGR will assist as technical and financial advisor throughout 

the sale. For more information about the license prospect, 

please visit www.agr.com/news. n 

CGG’s LCT software is licensed by many 

of the major international oil companies and 

independent operators. It is one of the key features 

of the 3-D earth model-building solution 

and has 2-D and 3-D modules for integrated 

geologic interpretation using gravity, gravity 

gradiometry and magnetics with seismic, 

controlled-source electromagnetic/moving 

magnet technologies, and geologic data. The 

software allows geophysicists to resolve, interpret, 

and visualize subsurface features ranging 

from salt and volcanic bodies to overthrusts 

and paleochannels. 

As well as being quick and cost-effective 

to acquire, gravity and magnetic data also are 

available on a multiclient basis and already exist 

in many of the exploration hotspots around the 

world. In fact, CGG now offers the most comprehensive 

proprietary multiclient geophysical library of airborne, 

land, and marine potential field data in the world, with some 14 

million line km (8.5 line miles) of aeromagnetic data, 1.2 million 

line km (731,000 line miles) of marine gravity and magnetic data, 

and 2 million land gravity stations worldwide. CGG has an active 

DUG_Aus_7x10 v2_Layout 1 6/5/13 9:36 AM Page 1 

program to increase library coverage and has recently added data in 

In this 3-D printed earth model of the Kings Sound case study gravity gradiometry and 

magnetic data have been jointly interpreted with sparse 2-D seismic and well log data to 

build a detailed model of the sediment lithofacies distributions in this frontier exploration 

area. (Image courtesy of CGG) 

Kenya and Namibia. To learn more about the company’s multidisciplinary 

data library or 3-D Earth model-building with potential 

field data, visit CGG at booth 530. 

CGG will be presenting the Kings Sound case study at the 

booth daily and will have the 3-D models available for visitors to 

peel back the layers. n 

Use promo code* DUGAUEAGE by 30 June 2013 and save $300 on conference registration. 

To register, visit dugaustralia.com or email conferences@hartenergy.com. 

GE Oil & Gas 

Presented by: 

Sponsors: 

A proud member of: 

Australia 

the new unconventional 

resource frontier 

Australia is already an unconventional production powerhouse – a world leader 

in coal-seam gas, and now in early stage development of shale gas and tight 

sand. The IEA estimates Australia has 700 Tcf of unconventional recoverable 

resources – that is the potential larger than the Marcellus and Haynesville 

shale plays combined! 

Challenges in Australia's resource development include minimal well control 

and seismic data, vast geographic expanses and varied prospective plays 

with hard-to-find sweet spots. Services are building scale, and mobilization 

costs are daunting. Hart Energy’s new DUG Australia conference will help 

accelerate the learning curve by sharing knowledge, know-how and 

networking. By attending, exhibiting or sponsoring at DUG Australia you can: 

• Identify important business and career opportunities in this 

emerging market 

• Meet local executives and company contacts who are already 

operating in Australia 

• Share insights on the latest thinking in reserve estimations for resource 

plays at a special pre-conference workshop with noted experts 

• Hear from the “US Shale Pioneers” and expand your knowledge 

based on the of the global unconventionals market 

• Learn best practices applied in the US in regard to successful 

drilling, fracturing and production strategies 

• Understand how US operators have developed their resources 

safely and effectively, and which strategies might be transferred 

to Australia 

EAGE SHOW SPECIAL – SAVE $300! 

Supported by: 

*Register for DUG Australia while at EAGE and save. Use code DUGAUEAGE and automatically 

save $300 off the $995 registration pricing. Offer expires 30 June 2013. 

EAGE 

Show Special* 

Save $300! 

27-29 AUG. 2013 

Royal International Convention Centre 

Brisbane, Australia 

dugaustralia.com 


15

Floor plan of the exhibition area 

Company 

Booth No. 

AAPG 107 

ABEM Instrument AB 2019 

Acceleware Ltd. 1830 

AGR 1572 

Airborne Technologies GmbH 1832 

All Ukrainian Association of Geoinformatics (AUAG) 4000 

ALT SA (Advanced Logic Technology) 1162 

altcom Ltd. 1723 

Amphenol Steward Enterprises 1532 

Amsterdam Petroleum Geoscience / T&A Survey 114 

Apex Spectral Technology Inc. 1736 

Archimedes Consulting Pty. Ltd. 984 

ARK CLS Ltd. 400 

ARKeX Ltd. 

1250 A 

ASC Ltd. 1730 

ASME Europe 1123 

Asociacion de Geologos y Geofisicos Espanoles del Petroleo 

(AGGEP) 4000 

Association of Geophysicists and Environmentalists of Serbia 

(AGES) 4000 

Association of Hungarian Geophysicists (MGE) 4000 

Association of the Geological Organizations (AGO) 4000 

Atlas Fluid Controls 2002 

Atlas Services Group 1361 

Australian Society of Exploration Geophysicists (ASEG) 4000 

AutoSeis Inc. 1640 

Avalon Sciences Ltd. 1262 

Azerbaijan Society of Petroleum Geologists (ASPG) 4000 

Badley Geoscience Ltd. 1734 

Baker Hughes 1020 

Balkan Geophysical Society (BGS) 4000 

Baoding Beiao Special Vehicle Manufacturing Co. Ltd. 118 

Baro Mek. Verksted AS 210 

Bashneftegeofizika 1700 

BAUER KOMPRESSOREN UK Ltd. 1822 

Beicip-Franlab 1124 

BG Group 760 

BGP 850 

Bolt Technology Corp. 1466 

BP Exploration Operating Co. 810 

Brazilian Geophysical Society (SBGf) 4000 

British Geological Survey U 10 

Cairn India Ltd. 2014 

Canadian Society of Exploration Geophysicists (CSEG) 4000 

CCK Media Technologies Ltd. 364 

CDP Consulting 366 

Company 

Booth No. 

CEPSA E&P 360 

CGG 530 

CGG JC 09 

Challenger GeoInstruments Ltd. 2010 

Chemostrat Ltd. 1905 

Chevron North Sea Ltd. 1540 

Chinese American Petroleum Association (CAPA) 4000 

Colombian Association of Petroleum Geologists (ACGGP) 4000 

Computer Modelling Group 1909 

Concept Systems Ltd. 1701 

Coraid Ltd. 2020 

Cortland Company Inc. 120 

Curtin University - Exploration Geophysics U 01 

Czech Association of Geophysicists (CAAG) 4000 

Dalmorneftegeophysica JSC 2023 

De Regt Marine Cables BV 462 

DECO Geophysical 110 

Dell Inc. 1732 

Deutsche Geophysikalische Gesellschaft (DGG) 4000 

dGB Earth Sciences BV 1114 

Dhahran Geosciences Society (DGS) 4000 

Directorate General Of Oil and Gas Indonesia 2000 

DMT GmbH & Co. KG 1162 

DMT GmbH & Co. KG 1260 

DMT Petrologic GmbH 1260 

Dolphin Geophysical AS 570 

DONG Energy 1560 

Dongeofizika Ltd. 1726 

DownUnder GeoSolutions 870 

DPTS Ltd. 1172 

Dynamic Technologies 2003 

EAGE Student Court 1105 

EBN B.V. 1826 

ELIIS 880 

EMC 266 

EMGS ASA 730 

Energistics 700 

Engenius Software 680 

ENRES International 1112 

ENTHOUGHT 264 

Environmental Systems Research Institute Inc. ESRI 411 

EnVision AS 1270 

EOST - University of Strasbourg U 03 

EPI Group 1536 

Epistemy Ltd. 1833 

ERA Ltd. 2020 

Company 

Booth No. 

ESG SOLUTIONS 1160 

European Association of Geoscientists & Engineers 1200 

European Geosciences Union (EGU) 4000 

Exploration Electronics Ltd. 1033 

Extron UK 1600 

FairfieldNodal 350 

ffA 1332 

FGPS International Ltd. 200 

Fluid Inclusion Technologies CA 06 

FolloWave Ltd. 1908 

FracRock International 1570 

Fraunhofer ITWM 1270 

Fugro Oceansismica S.p.A. 1842 

Fugro Survey AS 1030 

Fugro Survey Ltd. 1842 

Gardline 480 

GEDCO 960 

GEM Advanced Magnetometers 100 

GEO 2014 2035 

GEO ExPro (GeoPublishing Ltd.) 1304 

Geodynamics Research Group - ITB U 06 

Geofizyka Kraków S.A. 470 

Geofizyka Torun S.A. 1170 

GeoGlobAll Group 1644 

GeoGuide Consultants Ltd. 1835 

GEOKINETICS Inc. 420 

GeoKnowledge AS 712 

Geological Society of London 1800 

Geomatrix Earth Science Ltd. 1038 

Geometrics 1620 

Geomotive 1180 

GEOPARTNER SP. Z O.O. 123 

Geophysical Data Systems Ltd. (GDS Ltd.) 1824 

Geophysical Services Ltd. 366 

Geophysical Survey Systems Inc. (GSSI) 1620 

Geophysik GGD mbH 117 

GeoPol AS 1550 

GeoScience Ltd. 1836 

Geosoft Europe Ltd. 

1250 E 

Geospace Engineering Resources International 330 

Geospace Technologies 330 

GEOSVIP JSC 982 

GEOSYSTEMS LLC 982 

Geotec SpA 119 

GEOTECH Holding 240 

GeoTomo LLC 1032 


Company 

Booth No. 

Geotrace 430 

GEOVARIANCES 124 

GEOVERS Ltd 1362 

Global Geophysical Services Inc. 1422 

GLOBE Claritas 1306 

Guralp Systems 1725 

Halliburton Energy Services 910 

Hampson-Russell Software & Services 530 

Hannon Westwood CA 03 

Hart Enery Publishing 2012 

Hellenic Geophysical Union (HGU) 4000 

Heriot-Watt University - ETLP U 02 

Hewlett Packard 1840 

Hitachi Data Systems 1534 

HOT Engineering GmbH 1126 

Hydroscience Technologies Inc. 800 

IDS - Ingegneria dei Sistemi S.p.A. 1162 

IHRDC 1120 

IHS Global Ltd. 610 

Ikon Science 970 

Industrial Vehicles International 1720 

Infinity Seismic 417 

INOVA Geophysical 920 

INT 1110 

Interica 284 

Intrepid Geophysics 281 

ION Geophysical Corp. 630 

IPTC 1670 

IRIS Instruments 1620 

Irkutsk Electroprospecting Co. 1644 

iSeis and Seismic Source Co. 802 

ISI International Seismic Interpretation GmbH 1420 

iSys - The Imaging Systems Group Inc. 1002 

Italian EAGE-SEG Section 4000 

Jaguar Exploration Inc. 1911 

Jason 530 

Kinemetrics Inc. 1620 

KMS Technologies 1722 

Kongsberg Maritime 1430 

Kuwait Oil Company 1320 

Lab for Integration of G & G U 09 

LandOcean Energy Services Co. Ltd. 370 

LARGEO Group of Companies LLC 714 

Learning Geoscience (EAGE) 1122 

Leobersdorfer Maschinenfabrik GmbH & Co.KG LMKR 270 

Lynx Information Systems Ltd. 1903 

Company 

Booth No. 

Maersk Oil 310 

MagSeis AS 121 

MALÅ Geoscience AB 2019 

Marac Enterprises Inc. 

1250 C 

Marine Arctic Geological Expedition (MAGE) 710 

Maritim Equipment AS 1550 

McPhar International Pvt. Ltd. 

1250 G 

MicroSeismic Inc. 1010 

Mitcham Industries Inc. 230 

Mørenot Offshore AS 1550 

Mount Sopris Instrument Co. Inc. 1162 

Nanometrics Inc. 116 

National Oceanography Centre U 04 

Nautilus Ltd. 1522 

NCS Subsea 200 

NEFTEX 1530 

NEUMAN & ESSER GROUP 1642 

Nexans Norway AS 682 

Nigerian Mining and Geoscience Society (NMGS) 4000 

NORSAR Innovation AS 1336 

Nova Scotia Dept. Energy 1724 

Nubian Consulting Ltd. U 07 

Nvidia Ltd. 1732 

Octio AS 1662 

Offshore Engineer 2012 

Offshore & Trawl Supply AS 210 

Oil And Gas Institute 1902 

Oil&Gas of Lomonosov Moscow State University U 05 

Oilfield Technology 2012 

OMV Aktiengesellschaft JC 05 

Onsite OHS 1360 

OptaSense 1846 

OYO Corp. 1620 

PanTerra Geoconsultants B.V. 414 

Paradigm 1230 

Parallel Geoscience Corp. 

1250 F 

PartnerPlast AS 210 

Paulsson Inc. 108 

PBG Ltd. 282 

Petroleum Geo-Services 620 

Petroleum Geo-Services JC 06 

PetroMarker AS 244 

Petronas 1460 

PetroSkills 1220 

Petrosys Europe Ltd. 1350 

Phoenix Geophysics Ltd. 

1250 D 


Company 

Booth No. 

PhotoSat 115 

PMI Industries Inc. 1102 

Polamco Ltd. 2032 

Polarcus 550 

Poseidon Offshore (Safety and Health) Ltd CA 02 

Premier Oil Plc 2033 

PROSPECTIUNI SA 1330 

PRT Ltd. CA 01 

Qeye Labs 111 

Quantum 1915 

R.T. Clark Companies Inc. 

1250 H 

READ AS 242 

Reservoir Imaging Ltd. 772 

Resoptima AS 1910 

Rigzone 360 

ROBERTSON 530 

Robertson Geologging Ltd. 1620 

Rock Deformation Research Ltd. 1036 

Rock Flow Dynamics 1307 

RockEye Geo Tech LLC 1280 

Romanian Society of Geophysics (RSG) 4000 

Roxar Software Solutions AS 460 

RPS Energy 1522 

RPS-Knowledge Reservoir 283 

RSI 716 

RXT - Reservoir Exploration Technology ASA 431 

SAOGIET Poland 4000 

Saudi Aramco 640 

Saudi Geophysical Consulting Office 580 

Sauer Compressors UK 363 

Scandinavian Visualization Society (SCANVIZ) 4000 

Schlumberger JC 12 

Schlumberger 930 

Scientific Council of Oil and Gas of the Croatian Academy of 

Sciences & Arts 4000 

Scintrex 

1250 B 

Scout GTS-Geotech Group JC 04 

Seabed Geosolutions 820 

SeaBird Exploration FZ LLC 101 

Searcher Seismic 380 

Seismic Equipment Solutions 1305 

Seismic Image Processing Ltd. 472 

Seismic Instruments Inc. 1303 

Seismic Profile 2012 

Seismic Source Co. 802 

SeismoShelf Ltd. 280 

Seismotekhnika 122 

Senergy 1912 

Sensor Technology Ltd. 417 

SERCEL 520 

SEVMORGEO 2001 

Sevmorneftegeofizika (SMNG) 1526 

SGS Horizon B.V. 1334 

Sharp Reflections 1270 

Shell International Ltd. 670 

Siberian Geophysical Research Production Co. 2031 

Siemens, Subsea 464 

Silixa Ltd. 1524 

SINOPEC Geophysical Corp. 1440 

SLR Consulting 1917 

Society of Exploration Geophysicists 1904 

Society of Exploration Geophysicists of Japan (SEGJ) 4000 

Society of Petroleum Engineers 2021 

Society of Petroleum Geophysicists (SPG India) 4000 

Sonardyne International Ltd. 1308 

Spectrum 1300 

SPIE Oil & Gas Services 1834 

SPT Group Norway AS 1001 

Statoil ASA 510 

sTec Inc. 1901 

StratoChem Services 1900 

System Development Inc. - SDI 780 

TAQA Bratani Ltd. 1650 

TechnoImaging 112 

TEEC 1420 

TEECware GmbH 1420 

Teledyne Geophysical Instruments 1410 

Teledyne Impulse 1410 

Teledyne Marine 1410 

Teledyne RD Instruments 1410 

Teradata 2030 

TERRASYS Geophysics 1420 

Tessella 1844 

TGS 860 

TIBCO OpenSpirit 1352 

Total 320 

TRE 412 

Trelleborg PPL Ltd. 1080 

Troika International Ltd. 1101 

Tsunami Development, LLC 500 

Tullow Oil Plc 410 

Turkish Association of Petroleum Geologists (TAPG) 4000 

Ukrainian Association of Geologists (UAG) 4000 

United Oilfield Services Sp. z o.o. 362 

University of Calgary U 07 

Upstream Oil & Gas Newspaper 2012 

Upstream Technical Consultants JC 08 

US Seismic Systems Inc. 1820 

VARD 1660 

Vehicle Source Products Inc. 1532 

Verif-i Ltd. 980 

Vibrometric Oy 1162 

VIKING INTERNATIONAL LTD. 1164 

VNIIOkeangeologia 106 

VSG & FEI Co. 1034 

W.L. Gore & Associates, Survey Products Group 1520 

Weatherford 220 

Weihai Sunfull Geophysical Exploration Equipment Co. Ltd. 416 

WesternGeco Uniq System Sales 960 

Westheimer Energy Consultants Ltd. 262 

WGP 402 

Wiley 1907 

Wireless Seismic Inc. 1630 

Working Smart Ltd. JC 01 

World Oil 2012 

Xi’an Senshe Electronic Technology Corp. 600 

xPort Group Inc. 1532 

XtremeGeo 2022 

Zhaofeng(Xushui)Sensor Equipment Co. Ltd. 1302 

Zhuozhou HuaFei Commercial Trading Ltd. 1801 

Zonge International Inc. 415 

ZZ Resistivity Imaging Pty. Ltd. 1914 

All details correct at press time 

17

Deeper Insight into Hydrocarbon Prospects 

Interpretation system enables rapid identification of stratigraphic architectural elements. 

BY Wes Hamlyn, Paradigm 

Three-D seismic data provide rich and varied information 

about the subsurface environment. This robust remote 

sensing method has enabled the oil and gas industry to 

comprehensively map geological structures, predict lateral 

changes in depositional facies, and estimate lithological and 

pore fluid variations. 

The primary investigator of these data, the seismic interpreter, 

is tasked with extracting geologically meaningful 

information from seismic data volumes covering hundreds 

to thousands of square kilometers. In the case of stratigraphic 

interpretation – a key approach to understanding depositional 

environments, reservoir facies distribution, and fluid migration 

pathways – modern 3-D seismic data can provide images of a 

quality approaching that of aerial photography. 

The challenge comes with trying to identify prospective 

locations in a 3-D seismic volume. Consider that a moderately 

sized 3-D survey contains upwards of 150 billion data 

samples. How does an interpreter locate the few thousand 

samples that contain information pertaining to a hydrocarbon 

reservoir? Hunting for less than 0.0001% of the samples in 

a seismic volume can amount to searching for a needle in a 

very big haystack. 

To tackle these stratigraphic investigations, interpreters 

require in-depth knowledge of facies models, depositional 

environments, and a wealth of modern analogues. They also 

require an interpretation system that will allow rapid isolation 

of stratigraphic intervals, stratigraphic slicing and visualization 

of seismic amplitudes, and volumetric rendering of seismic attributes 

within prospective intervals. The ability to interactively 

manipulate colors, calculate and test many seismic attributes, 

and co-render several seismic volumes greatly improves the 

chance of locating a stratigraphic prospect. 

Typically the “interesting” geology lies hidden in weak, 

discontinuous seismic reflections. When viewed in a vertical 

cross section, the subtle meaning of amplitudes can easily be 

overlooked. When viewed along a stratigraphic slice, however, 

the lateral variation in amplitude patterns can be enlightening. 

Lateral facies variations, erosional processes, and sediment 

remobilization features all can be readily extracted from these 

easily overlooked seismic events. 

With the release of Paradigm 2011.3, the stratigraphic interpretation 

capabilities of the SeisEarth interpretation system 

have been extended to support rapid stratigraphic prospecting 

in the same visualization canvas used for multisurvey regional 

interpretation. New workflows enable geoscientists to perform 

single-horizon and multihorizon volume flattening (i.e. vertical 

A stratigraphic slice through a deepwater depositional interval reveals 

slump features, debris slides, and an interpreted fluid migration 

fairway leading updip (green arrow) to a high-amplitude anomaly 

associated with a structural high (potential direct hydrocarbon indicator). 

(Data courtesy of AWE Ltd.) 

shifting) and horizon-parallel and multihorizon proportional 

slicing through seismic data volumes. In conjunction with the 

3-D Propagator horizon tracker, interpreters can interactively 

slice seismic data volumes along interpolated stratigraphic layers 

with subsample precision while maintaining a regional perspective 

of the complete depositional system. 

Complementary to surface-based stratigraphic analysis, the 

voxel rendering technology developed in VoxelGeo has been 

embedded into the 3-D canvas. Through the use of GPUs, 

where hundreds of cores are deployed to carry out seismic 

volume rendering, this visualization process removes artifacts 

to reveal details of the geology and accelerate refresh speed. 

By deploying this technology in the same application used for 

multisurvey interpretation, interpreters can carry out detailed 

volume rendering of stratigraphic features without the need to 

move from one application to another. 

To coax subtle stratigraphic details from the interval under 

investigation, interpreters may generate many seismic attribute 

volumes. These volumes can easily exceed the available workstation 

memory and limit the ability to perform multiattribute 

interpretation. To address this limitation, Paradigm 2011.3 can 

roam through seismic volumes directly from disk. By automatically 

adjusting display resolution, reading data using multiple 

processing threads, and leveraging a new sparse brick seismic 

file format, geoscientists can simultaneously co-render, blend, 

slice, and interpret many seismic attribute volumes even on 

workstations with limited system memory. 

To learn more about Paradigm 2011.3, visit Paradigm at 

booth 1230 during EAGE 2013. n 

www.eage.org 

www.eage.ru 

Geosciences – Investing in the Future 

Call for papers 

Deadline 1 October 2013 

6 th Saint Petersburg International Conference & Exhibition 

7-10 April 2014 

Saint Petersburg, Russia 

Geoscientists Invited to 

Submit Entries for 

Photo Contest 

The photo contest, introduced a couple of years ago, is 

already a regular and much appreciated feature at EAGE 

annual meetings. However, for the first time EAGE will 

organize it in cooperation with the European Federation 

of Geologists (EFG). Together, EAGE and EFG can reach 

many more people who would like to submit a photo and 

can showcase entries not only at the annual conference and 

exhibition but also at other events. The organizations can 

reach a larger audience of professionals, many of whom may 

have been unaware of the photo contest or EAGE before. 

The 12 best photos will be displayed at the 75th EAGE 

Conference and Exhibition incorporating SPE EURO- 

PEC 2013 being held in London on June 10 - 13, 2013. If 

previous years are any guide, contest organizers expect many 

entries of excellent quality. Moreover, the 12 best photos will 

be printed in a calendar and also displayed during the EFG 

Council Meeting and Workshop. 

All members were invited to submit photos under the 

theme of “geoscientists at work,” meaning that images relate 

to geoscientific jobs that focus on applying geosciences and 

engineering in the field. All EAGE and EFG members will 

have the opportunity to cast their vote for the best pictures. 

Last year’s EAGE winner was a photo of Simon Ball 

and John Smythe titled, “Surveyors plot the shot points 

amongst the icebergs.” The photo was taken in Cook Inlet, 

Alaska, and was rewarded with the first prize: a Nikon 

digital reflex camera. Submit your photo, win prizes, and 

get a spot in the exhibition! n 

15931 diverse advertenties.indd 5 22-05-13 17:09 


Innovations in Logging Technology 

Tools provide accurate formation images and reservoir data. 

CONtributed By Weatherford 

Advanced logging technologies enable operators to make 

more informed reservoir management decisions, even in 

today’s more complex operating environments. Weatherford 

has developed and successfully deployed logging tools for 

open and cased holes that address operators’ needs in reservoirs 

of all types. 

Openhole logging is a well-established method for obtaining 

valuable reservoir data, but conventional wireline 

conveyance has limitations in complex well geometries and 

wellbore with hole quality issues. Risks include sticking and 

tool loss, as well as failing to reach the zone of interest and 

consequently to acquire reservoir data. 

Weatherford’s Compact suite of small-diameter, shortlength 

tools can allow for more efficient logging in laterals. 

The Compact microimager incorporates eight caliper arms 

to acquire high-quality imaging data, including visualization 

of complex structures and identification of faults, fractures, 

and sand-shale facies. The Compact cross-dipole sonic tool 

combines monopole and cross-dipole sonic technology to 

capture data that assist in well placement, wellbore stability, 

completion optimization, and maximizing reservoir productivity. 

These tools are deployed on Weatherford’s Assure 

systems, which consist of 10 conveyance methods, including 

well shuttle and pump-down/drop-off. These systems can 

help ensure reliable logging of longer horizontals by reducing 

the risk of tool loss or sticking. 

Weatherford has applied the Compact/Assure conveyance 

combo in many North American shale plays and globally in 

unconventional resource plays. Recently, an onshore operator 

in the UK selected the microimager and cross-dipole sonic 

tools to optimize completion design in a resource play containing 

sand, shale, and coal seams. The company deployed 

these tools in a 6-in. hole to a depth of 823 m (2,700 ft). The 

cross-dipole sonic data derived Stoneley fracture analysis and 

mechanical rock properties, while fracture density analysis 

was performed on the microimager data. The tools identified 

the presence of washouts, bed boundaries, and fracture reflections 

and confirmed that the fractures were open. With this 

information the operator optimized completion design and 

reduced costs. 

Using pulsed-neutron tools to evaluate reservoirs behind 

casing helps operators understand fluid-displacement mechanisms 

and assess a reservoir’s remaining reserves. However, in 

mature fields, reservoirs with low or mixed salinity, and unconventional 

gas plays conventional pulsed-neutron tools fail 

to accurately quantify hydrocarbon-saturation changes. The 

company’s Raptor pulsed-neutron tool is designed to provide 

accurate measurements through casing, even in historically 

tough-to-log conditions. 

The tool contains the industry’s first five-detector array: four 

lanthanum-bromide scintillation detectors and a fast-neutron 

detector. The design improves brightness for reduced signalto-noise 

ratio and enhances peak resolution for better spectral 

analysis, more robust temperature stability, and faster logging 

speeds. Mineralogy and shale-handling algorithms allow 

for analytical measurements of lithology, oil saturation, fluid 

saturations in high-brine formations, and three-phase saturations. 

Finally, characterization via Monte Carlo computational 

modeling accounts for the many variables in the borehole and 

reservoir environment. In addition, a group of highly trained 

production petrophysicists provides support to end users. 

The tool was trialed in a mature basin offshoreTrinidad 

and Tobago. Accurate reservoir surveillance was historically 

Airborne Technologies 

Launches New 

Aeromagnetic Aircraft 

Airborne Technologies has completed the development, 

testing, and European Aviation Safety Agency 

certification process for a new generation of geophysical 

survey platforms. 

A development team of aircraft engineers and geophysicists 

has modified a high-wing, twin-engine aircraft 

branded “TECNAM MMA” for the needs of airborne 

geophysical surveys. Engineers and scientists from the 

Vienna University of Technology, PICO Envirotec 

Inc., and the Geological Survey of Austria made major 

changes in the structural design of the data acquisition 

aircraft to reduce the magnetic and electrical field while 


Weatherford’s Compact microimager 

provides formation 

images for dip and fracture 

detection, sedimentary structure 

characterization, thin-bed 

evaluation, facies analysis, 

and orientated resistivity and 

dipmeter computation. (Images 

courtesy of Weatherford) 

challenged by the presence of low-salinity formation water, 

multiple fluid phases, and thin beds. A logging campaign involving 

four wells was initiated, each containing multiple and 

diverse target sands and all located behind casing. The tool 

successfully logged the reservoirs and allowed the operator 

to define fluid contacts and derive saturation profiles across 

various reservoirs, which subsequently helped optimize well 

placement for future reservoir targets. 

The company houses a global network of geoscience and 

engineering professionals known as Petroleum Consulting, 

which processes and interprets reservoir data from a wide 

variety of sources including LWD, surface logging, core samples, 

openhole logging, and microseismic monitoring. Focal 

areas include unconventional resources (shale gas and oil, tight 

gas, and coalbed methane), geomechanics, and enhanced oil 

recovery. The group also has dedicated production petrophysicists 

that process and interpret data. 

The profile and length of the Compact cross-dipole sonic tool facilitates 

flexible deployment in wireline or memory mode to mitigate 

the risk of bridging events and reduce nonproductive time. 

Petroleum Consultings’s shale expertise stems from experience 

in major North American plays. The group has assisted 

operators in the Barnett, Eagle Ford, Fayetteville, Haynesville, 

and Marcellus shales. Services include aggregating 

reservoir data from multiple sources; guiding decisions on 

well spacing, well placement, reservoir stimulation, and 

full-field development strategies; and shortening the learning 

curve in new plays. 

To learn more, visit Weatherford at booth 220. n 

increasing the platform´s overall performance. Hours 

of tests and calibration flights over the past 18 months 

as well as subsequent iterative modifications resulted in 

a reproducible “figure of merit” of 0.1 nT. With this 

specification the aircraft is able to measure horizontal 

magnetic gradient as well as a nose or tail boom configuration. 

Equipped additionally with a gamma-ray spectrometer 

or a gravity meter in combination with remote 

sensing such as laserscanner or hyperspectral sensors, the 

platform proved its multisensor capability. 

A comparison of results acquired with the TECNAM 

MMA versus existing geophysical surveys showed that 

the low magnetic noise envelope allows it to reveal unexplored 

anomalies. 

Equipped with the highest safety standards, all kinds of 

specific requirements on high resolution airborne surveys 

are met. The low acoustic noise level of the aircraft enables 

low-level flights without any adverse effects on the 

environment or the public. 

Visit Airborne Technologies at booth 1832. n 

19

Multiclient Services 

Ice Bear 

Nordkapp Basin 

West Loppa 

Barents Sea 

Norway 

Our success speaks volumes 

in the Barents Sea. 

Having been at the heart of recent discoveries in this area, WesternGeco 

continues to acquire multiclient seismic data in the Barents Sea to deliver 

the most accurate images of the subsurface using the latest high-resolution 

seismic acquisition technologies. 

Write your own success story with our multiclient data. 

Visit us at stand no. 930 

slb.com/multiclient 

© 2013 Schlumberger. 13-se-0051

Reservoir Focus for Giant Offshore Duo - Hart's E&P

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