Higher-Resolution Subsurface Imaging of Hydrocarbons

R&D GRAND CHALLENGES

Higher Resolution Subsurface Imaging

Jack Neal and Chris Krohn, ExxonMobil Upstream Research

Editor’s note: This is the fifth in a series control points. Selection of the right dep- and depositional bars hold the coars- of articles on the great challenges facing ositional model, facies distribution, and est sediments with the most porosity the oil and gas industry as outlined geostatistical analog depends on having while oxbow lakes and floodplain muds by the SPE Research and Development the sharpest, most detailed and accurate can be seen as potential barriers to flow. (R&D) Committee. The R&D challenges image of the subsurface possible—the Now imagine that instead of air between comprise broad upstream business Grand Challenge of Higher Resolution the observer and the geologic feature, needs: increasing recovery factors, Subsurface Imaging. you must see through countless layers in-situ molecular manipulation, Over the past century, the industry of rock with complex physical proper- carbon capture and sequestration, has relentlessly sought ways to improve ties that obscure or muddle your vision produced water management, higher subsurface imaging of hydrocarbons. of the delta below. Further imagine that resolution subsurface imaging of Canadian inventor Reginald Fessen- you have a handful of well penetrations hydrocarbons, and the environment. den first patented the use of the seis- in your delta that stretches over several The articles in this series examine each mic method to infer geology in 1917. A square kilometers and you want to see of these challenges in depth. White decade later, Schlumberger lowered an how produced and injected fluids move papers covering these challenges are electric tool down a borehole in France to between wells. available at www.spe.org/industry/ record the first well log. Today, advances The industry’s goal is to continuous- globalchallenges and allow reader in seismic and gravity data acquisition, ly improve the subsurface images needed comments and open discussion of electromagnetics, signal processing and to better find and produce hydrocarbons the topics. modeling powered by high-performance in reservoirs such as this. Obstacles to computing, and the nanotechnology rev- this goal include remote-sensing limita- olution are at the forefront of improved tions imposed by the physics of the rocks Introduction reservoir imaging. themselves (e.g. energy attenuation with It is hard to read road signs if you have In this paper, we will examine the depth, bed thickness and lateral extent poor eyesight, which is why driver’s challenges of getting higher resolution relative to signal wavelength, and vari- licenses are issued with restrictions subsurface images of hydrocarbons and able rock velocity and density properties requiring that corrective lenses must be touch on emerging research trends and that can scatter or complicate input sig- worn. Likewise, it is hard to find and technologies aimed at delivering a more nal), as well as instrumentation and com- exploit subsurface resources if you can’t accurate reservoir picture. puting power limits. On top of the tech- clearly see your targets or monitor the nology challenges, there are economic movement of fluids in the reservoir. The Problem Statement considerations. If it costs more to acquire Engineers now have powerful tools Hydrocarbon accumulations occur thou- an advanced dataset than you can hope to precisely model subsurface reser- sands of feet below the Earth’s surface to recoup from a development, the tech- voir production behavior, but a precise and the days of finding subsurface hydro- nology might as well not exist. We recog- answer is still wrong if it is derived from carbons through extrapolation of surface nize that absolute accuracy and precision an inaccurate subsurface description. geology are all but gone. Now explora- will never be achieved, no matter how Geoscientists make maps and rock prop- tion is done with remote sensing tools good our technology becomes, since all erty models of the subsurface by inter- that seek to generate sharper pictures measured data are imperfect. The “grand preting images that are produced from with greater detail of the lateral and ver- challenge” is to achieve the truly fit-for- remote sensing data. Analogs from mod- tical changes in subsurface rock layers purpose subsurface image at good eco- ern depositional environments and out- and sometimes the porosity and pore- nomic value. crop exposures guide subsurface data filling hydrocarbons we require. If you Research that addresses imaging interpretation to predict ahead of the bit, have ever seen an aerial photograph of limitations is advancing worldwide on a then postdrill geostatistics are used to fill a delta, you can imagine what a subsur- dizzying array of technologies, but the in stratigraphic details between wellbore face reservoir could look like—channels problem is complex. Sometimes the res-

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ervoir target is undermasking layers of medium highlight not only the challenge part of the challenge. Accurate place- salt, thrust sheets, or volcanics. It may to achieve higher resolution, but also ment of a target can be even more criti- be more than 30,000 feet below the sur- concerns on depth conversion. Diffract- cal and correct depth placement is espe- face, hidden within a producing field, or ed, attenuated, and multiply reflected cially important for exploration drilling have physical properties that are near- signal energy can result from the com- in areas of overpressure. Increasing com- ly indistinguishable from surrounding plex physical property structure of rock putational power, multicomponent and rocks. The problems generated by imag- layers to degrade subsurface imaging, but rich azimuth data collection, and algo- ing through a complex and unknown a higher resolution of the image is only rithm efficiency are bringing the industry forward toward a more accurate and detailed Earth model that uses all of the signals possible in seismology; even better seismic data acquisition and processing technologies are needed. Only a minuscule fraction of the subsurface can be directly observed: the *HW portion generally less than 12 inches in diameter that is penetrated by boreholes. 0RUH Directly observed, that is, if cored, oth- erwise indirectly observed through well logs. Well logs can sense a short distance into the formation, depending on the character of the signal/receiver setup, but the tradeoff is depth into the formation at the expense of vertical resolution. Moving just a few meters away from IURP the wellbore puts reservoir imaging back into a remote sensing problem with limitations for our ability to illuminate and view the region. Generally, sources and \RXU receivers must be placed far away at the surface and energy propagated a long distance to the target and back. Corre- spondingly, there is a large drop in resolution. Compare this situation with the &RUH medical imaging problem, which allows X-ray sources and detectors to be used With reservoirs becoming increasingly complex, around the patient. In some cases, geo- you need the most accurate information you can physical sources and receivers can be get to better understand your reservoir. placed much nearer to the zone of interest along wellbores, but then it like try- Weatherford Labs helps you get more from your core by combining an unsurpassed global team of geoscientists, ing to see through a key hole; the source engineers, technicians and researchers with the industry’s and receiver locations may or may not most comprehensive, integrated laboratory services adequately illuminate the region that we worldwide. From core analysis, sorption, geochemistry want to image. and isotopic composition to detailed basin modeling and Reflection seismology is the most comprehensive data packages, we provide you with real reservoir rock and fluid information that hasn’t been ZHDWKHUIRUGODEVFRP used remote sensing method in geophys- distilled by a simulator or iterated by software. ics. Seismic data delineates subsurface velocity and density variations, but if ™ We call it “The Ground Truth ” – giving you the accurate rock properties are favorable, they can be answers you need for better reservoir understanding. You’ll call it a better return on your reservoir investment. To learn used to distinguish hydrocarbons versus more, contact [email protected]. formation water in a reservoir. Repeated 3D surveys over the same area can track fluid movement through time (4D). How- ever, 4D surveying has its challenges:

More_Core_4.4375x7.5_4C.indd 1 1/4/2011 8:45:11 AM 46 JPT • MARCH 2012 R&D GRAND CHALLENGES

topic for research and development. The understanding of these rocks as reservoirs is still in its infancy compared with conventional reservoirs. Therefore, addi- tional research into resolving controls on unconventional resource producibil- ity remains a challenge.

Reflection Seismology What progress is being made toward delivering more accurate and higher resolution subsurface images? Seismology has earth physics challenges to overcome. Signals sent into the ground are reflected, refracted, diffracted, mode converted, and attenuated as they pass through layers of the earth. At greater depth, signal attenuation reduces resolution. Under Fig. 1—Processing speed in flops (floating point operations per complex geology, distortion of the wave- second) through time of the top 500 published computers and the field can give false images. The past few sum total global capacity. years have seen a flurry of innovation and image improvement, due largely to time to acquire, process, and accurately has not reached broad application. There advances in computing speed, which con- align with past surveys, limits in coverage is a great need for improved technolo- tinues to follow Moore’s Law by averaging caused by production facilities, and lim- gies that image reservoirs and pore-fill- a doubling of processing speed every year its in resolution due to earth physics and ing fluids at high resolution within pro- up to the current record holder that is illumination. Furthermore, it is costly. ducing fields while operating within the capable of 8 petaflops (8 quadrillion cal- Emerging technology of cross-well constraints imposed by the environment. culations per second—Fig. 1) processing. geophysical imaging offers to bridge the With the growth of unconvention- What all that computing power allows is gap between high resolution well logs and al resources that require stimulation to the mathematical transformation of 10s surface seismic resolution, but the tech- produce at economic rates, imaging of to 100s of terabytes of data recorded in a nology has significant limitations and the stimulation itself has become a hot modern survey into images that geoscientists can interpret. The processing capability increase has occurred in parallel with data recording advancements such as multicomponent and high effort, multi-azimuth surveys now common in areas of the greatest imaging challenges such as the Gulf of Mexico sub-salt plays. Enabling this type of data-rich survey is instrumentation to record an increasing number of channels, a capability that has doubled every three and one-half years since 1970, with 1 million channel acquisition in the near future. These new acquisition capabilities seek to illuminate geology previously hidden by complex rock structure. Additionally, data Fig. 2—Dual coil shooting acquisition. Left, two source and recording vessels, S1 and S2, sail along two circles (12–15 km in diameter) that recorded at far offset angles and azi- have the centers separated by dx and dy distances. Right, coverage muths, capturing shear waves in addi- fold (data density) and bin offset-azimuth distribution (spider tion to compressional waves, can pro- diagram—data richness); the bin size used to calculate the attributes vide information on rock anisotropy was 25 m×25 m (Moldoveanu and Kapoor, 2009) that may be driven by differences in

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lithology, fracture density, or pore flu- up recently with increased high-per- ciency in acquiring high-density surveys ids. Greater recording capabilities have formance computing, instrumentation (Beasley, 2008), now extended into the led to new methods of acquisition and with greater recording channel counts, marine realm. With new dual coil acqui- processing aimed at capturing a broad- increased multicomponent data acquisi- sition surveys, very high data fold and er range of frequencies (bandwidth) of tion demand, and the constant pressure full azimuth coverage can be achieved seismic signal, without introducing too on cost reduction. Data collection from (Fig. 2) to better stack and migrate seis- much noise. Increased bandwidth is a simultaneous source locations has the mic data, improve signal-to-noise ratio key to higher resolution seismic reflec- potential to significantly increase effi- and resulting image quality, and it can be tion images. The current frontier for seismic Visit us at OTC acquisition includes cableless and wireless recording, high-density rich-azi- Arena Booth 8115 muth recording with simultaneous sources, higher quality land seismic, and low frequency signals. Both cableless and wireless recording are very attrac- tive concepts, enabling easier and safer seismic data acquisition in remote or sensitive environments. Cableless sys- Loosen up. tems with local memory are commer- cially available, but the data cannot be collected in real time. Although not yet ready to be deployed at large commercial scale (Crice, 2011), wireless sensors are promising. Success will come if the limitations of wireless transmission bandwidth needed to accommodate seismic data recording rates and volumes can ™ be overcome, and if recording and real- time QC objectives can be met through Free your stuck drill string advances in memory and battery power. with Knight Oil Tools’ Several contractor groups are promot- ™ ing this technology, including a Shell/ Megaton Drilling Jar HP partnership Nothing can stop your drilling Higher quality land seismic data is operation when you strike with the focus of the 2011-2014 SEAM II proj- Megaton force. The extraordinary ect (Society of Exploration Geophysicists Megaton drilling jar with patented Advanced Modeling), an industry asso- Ulti-Torq™ connections is a proven ciate group targeting three core chal- performer that operates by the simple lenges: high density geometries, near up-and-down motion of the drill string. surface complexities, and fractured res- Its unique design combines both ervoir characterization (www.seg.org/ hydraulic time-delay release and an SEAM). A key enabling technology for optional internal mechanical lock better land seismic data is simultane- in one dual-acting drilling jar. ous sourcing, which is the capabili- The operation is simple. ty to acquire returning signal from one The results are earth shattering. source while another is still propagat- ing through the earth. Mobil developed and licensed a High Fidelity Vibroseis System (HFVS) in the late 1990s to sepa- rate data from multiple vibrators operating simultaneously (Krohn and Johnson, www.knightoiltools.com 2006). Although the concept is not new, ©2012 – Knight Oil Tools, All Rights Reserved. widespread application has only picked

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Fig. 3—An east-west line image of a 3-D data set in the Gulf of Mexico: (a) Kirchoff migration and (b) RTM (Kim et al., 2011)

made even more cost-effective by using is seismic modeling, in which geolog- is acoustic RTM or isotropic elastic RTM, simultaneous sources. ic realizations are converted into seis- using a simplified version of the wave Low-frequency data has been a tar- mic images by passing a seismic signal equation. Elastic RTM without isotropic get for processors seeking greater band- of some frequency through the geologic assumptions is emerging with increas- width for years. This low-frequency model. Inversion modeling can be done ing computing power to include more of extension of bandwidth is particularly at many scales and with different lev- the wavefield in image reconstructions, important in its ability to penetrate deep- els of conditioning. Quantitative rock promising even more imaging improve- er into the earth and through rugose lay- property inversion can be done at a field ment. Inverting for an earth model that ers such as basalt, salt and volcanics. scale with well log calibration of the seis- matches the recorded data takes massive Also, a body of work exists to suggest mic signal. Of interest to engineers are computing power and could be limited in low-frequency signals and spectral anal- parameters such as porosity and per- effectiveness without the fullest possible ysis as a direct hydrocarbon indicator meability that must be derived through bandwidth, especially the low-frequency (DHI) tool (Walker, 2008). Challenges to calibrated transforms using well data or spectrum. RTM data has demonstrated acquire this data type lie in the need for empirical approximations. A good inver- improved sub-salt imaging, but it cannot nonstandard sources, including passive sion produces a geologic realization that solve all the subsurface resolution and monitoring of earthquake signals, and matches the recorded seismic signal. Full detection challenges such as fluid effect, increasing signal-to-noise ratios. Gen- wavefield inversion is the purest form subvolcanics imaging, and complicated erating sufficient low-frequency signal of the technique. In it, all output data velocity thin bed imaging. energy requires very large sources. The collected from the reflected, refracted, presence of much larger environmen- diffracted and converted energy modes Imaging Within a Field tal noise and surface-wave noise further are used to create a visco-elastic earth Time-lapse (4D) acquisition of seismic complicates low-frequency data acqui- model. Currently, this capability is out of data over a producing field to image sition. Low-frequency data may ulti- reach despite marketing claims of “full movement of fluids in a reservoir has mately become another competitive DHI wavefield inversion,” which really invert obvious benefits, but the practical mat- tool; even if not, the collection of this parts of the wavefield using simplifying ters of actually achieving that objective data may be a key to the next break- assumptions. Still, amazing results have have slowed deployment of the technol- through in subsurface imaging—full been achieved by partially solving the ogy. In a recent special section of The wavefield inversion. problem, thus showing the promise of Leading Edge, case studies presented Full wavefield and general seis- the technique. show the promise and challenges to 4D mic inversion is the other aspect of Reverse time migration (RTM) is a seismic data acquisition as it evolved improved subsurface resolution that processing technique that uses the wave over the past 20 years to gain wide accep- increased computing power enables. equation in reverse to model the subsur- tance in the marine environment, partic- Seismic inversion is the process to con- face velocity field and obtain improved ularly among the reservoir engineering vert seismic data into a rock property images of geology at steep dips or under community as a complement to produc- realization. The flip side of this process salt (Fig. 3). Current industry capability tion logging techniques (MacBeth and

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4-D seismic anomalies show anisotropic trends

Fig. 4—Effect of 4D seismic interpretation at Marlim field, offshore Brazil, on the field flow model. New 4D data water flood anomalies confirmed a new conceptual sedimentological model of the field that differed from the flow model constructed just from well data (Johan et al, 2011)

Michelena, 2011). Planning early in field Alternatives to Surface Seismic veillance in the giant field (Ferguson et development for 4D seismic acquisition Not all technologies targeted to improve al., 2008). This work highlighted the over the field life is beneficial because subsurface resolution of hydrocarbons challenges to achieving a reliable base- repeat surveys take significant time to involve traditional reflection seismol- line for corrected measurements, but acquire, process, and accurately align ogy. Advances in field instrumentation also showed the technology feasibility. with past surveys. Permanent geophones sensitivity and robustness combined Modeling work to track CO2 injection for or ocean-bottom cable options help with improvements to computer mod- sequestration and enhanced oil recov- some of the alignment challenges and eling capabilities have brought several ery shows a time-lapse microgravity sig- can produce a better result. The upfront alternative geophysical sensing technol- nal when oil and water are displaced, cost of this investment is a difficult hur- ogies onto a higher resolution hydro- consistent with an independent analy- dle for many operators to overcome. It is carbon imaging plane. Micrograv- sis with seismic data (Krahenbuhl et al., hard to quantify before production start ity, crosswell seismic, and controlled 2011). High-quality reservoir models, just how much benefit 4D images will source electromagnetic (CSEM) imaging precise measurement, and careful quan- have over a field’s life. The one constant are alternative geophysical technologies tification of uncertainty are required of 4D acquisition seems to be that the that have been used in field examples to gain full benefit from time-lapse results will surprise you. Repeat survey to track fluid movement in reservoirs. microgravity but the low cost makes the results continually change flow models Time-lapse microgravity technology effort worthwhile. to drive better field production history shows promise as a low-cost alternative Crosswell CSEM was described as a matches, which improve predictability to 4D seismic for shallow reservoirs as practical subsurface hydrocarbon detec- and bypassed pay identification (Johan instrumentation and modeling capabili- tion tool by Wilt et al. in 1995. As instru- et al., 2011). If the data are collected ties improve (Krahenbuhl et al., 2011). mentation and modeling capabilities and processed correctly, those surprises This technique was meticulously applied have improved, the technology moved should help an operator to more profit- over Prudhoe Bay, Alaska, for a period from basic detection to potentially pro- ably develop fields, even if they dramati- from 2003 to 2007 to confirm a micro- viding higher resolution imaging of sub- cally change the existing understanding. gravity signal to enable water flood sur- surface fluid movement. By inducing

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ponent or azimuthal seismic data can identify anisotropy that may be related to fracture density and orientation. Such knowledge is useful in well stimulation frac design or to avoid areas where frac- tures may have connected aquifers to tight gas reservoir. Multicomponent and azimuthal seismic also has the potential to identify areas of greater organic con- tent since organics in shale have been demonstrated to produce a transverse anisotropy that can impact Vp and Vs and produce an amplitude versus offset effect (Vernik and Nur, 1992). Microseismic data acquisition technology records seismic energy generated from rocks breaking in the subsurface Fig. 5—Crosswell resistivity profile after steam injection, recording as a result of induced fracture stimu- a dramatic drop in resistivity once the formation has been heated (Marion et al., 2011) lation in a well. Data from the recording of microseismic events can be used an electrical signal into the ground and Austin, seeks to “develop intelligent sub- to predict a well’s relative productivity recording resistance between source and surface micro and nanosensors that can or identify incomplete stimulation and recorder locations, the technology pro- be injected into oil and gas reservoirs infill opportunities. In new shale gas vides insight, through advanced mod- to help characterize the space in three plays where the geomechanics of the eling, into the distribution of resistive dimensions and improve the recovery of shale reservoir are unknown, microseis- hydrocarbons and conductive formation existing and new hydrocarbon resources” mic is now routinely collected to deter- waters. With source and receiver pairs at (www.beg.utexas.edu/aec/mission.php). mine play potential and to confirm iso- reservoir depth between two wells, the Conceptually, nanomaterials can be used lation from adjacent aquifer zones. In resistance structure can indicate reser- as highly mobile contrast agents that established plays, the technology can voir complexity at higher resolution than can be detected with remote sensing. help optimize lease development by surface remote sensing methods such as If imbued with intelligent sensing and identifying refrac needs or calibrate well seismic data. Crosswell seismic acqui- recording capabilities themselves, nano- drainage to space infill drilling more sition can also offer resolution uplift meter-scale machines may one day fully efficiently and avoid interference. New although challenges of cost and con- illuminate and describe subsurface res- insight into the nature of fracture stimu- ditions for downhole sources remain, ervoir conditions. Research to achieve lations is now emerging with microseis- and similar results might be obtainable these goals is under way today, even if mic moment tensor data recording that through offset vertical seismic profiling. commercial application is a long distance combines with geomechanical analysis While CSEM can produce unique insight into the future. The promise of higher to produce a clearer picture of stimu- under the right circumstances, there resolution subsurface imaging through lated rock volume and ultimately assist are challenges to overcome in modeling functionalized nanocomposite materials unconventional reservoir model simula- non-unique solutions to resistivity pro- injection into reservoirs for remote sens- tions (Maxwell and Cipolla, 2011). files and finding a solution to the limita- ing is one to watch. tion that data be collected in openhole or Conclusion specially cased wells. If these hurdles can Imaging Unconventionals Higher resolution subsurface imaging be surmounted, crosswell CSEM could No overview of higher resolution subsur- of hydrocarbons is one of SPE’s Grand become a powerful tool in brownfield face imaging would be complete these Challenges for a good reason. As long developments to identify bypassed pay days without a discussion of uncon- as the industry has sought to find and and image waterflood sweep efficiency. ventional resources, namely tight gas exploit subsurface resources, it has Nanotechnology is at the cutting and shale gas/liquids. These resources sought to see them better. The challenge edge of technology for higher resolu- have distinct imaging needs. For exam- is difficult. We are largely restricted to tion reservoir imaging with fundamental ple, natural fracture imaging in the sub- source and receiver locations on the research ongoing at many universities. surface is sought to determine geologic surface of the earth, trying to illuminate The Advanced Energy Consortium (AEC), sweet spots or areas to avoid, depending deep targets and resolve images through managed from the University of Texas at on your play success needs. Multicom- a complex and unknown medium.

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The good news is that much progress References Wilt, M.J., Alumbaugh, D.L., Morrison, H.F., is being made to improve our capabilities Crice, D., 2011. Emerging market for seismic Becker, A., Lee, K.H. and Deszcz-Pan, M., and data coverage. Seismic data covers acquisition systems without cables still has 1995. Crosswell electromagnetic tomo- much of the planet, with more and high- problems to solve, First Break, v. 29, pp graphy: System design considerations and er quality 3D and 4D data each year. 81–84. field results, Geophysics, v. 60, pp. 871–885. Advanced computing capabilities permit Johann, P., Abreu, C.E., Grochau, M., and Marion, B., Safdar, M., Wilt, M., Zhang, P., construction of more detailed inversion Thedy, E., Advanced Seismic Imag- Loh, F. and Nalonnil, A., 2011. Crosswell models from the collection of high-qual- ing Impacting Brazilian Offshore Bra- Technologies: New Solutions for Enhanced ity datasets. Improved acquisition tech- zil Fields Development, http://dx.doi. Reservoir Surveillance, Paper SPE 144271 nology is gathering new data in places org/10.4043/21934-MS presented at the presented at the SPE Enhanced Oil Recov- and ways previously beyond reach. New Offshore Technology Conference, 2–5 May ery Conference, 19–21 July 2011, Kuala nanotechnologies offer great potential 2011, Houston, Texas. Lumpur, Malaysia. for improved subsurface imaging with Kim, Y.C., Ji, J., Yoon, K.J., Wang, B., Li, Z. Krahenbuhl, R., Li, Y. and Davis, T., 2011. advances in the fundamental sciences, and Xu, W., 2011. SS: The Future of Seismic Understanding the applications and limi- but this potential remains a distant real- Imaging; Reverse Time Migration and Full tations of time-lapse gravity for reservoir ity. The “bad” news is that earth physics Wavefield Inversion—Multi-step Reverse monitoring, The Leading Edge, Vol. 30, No. complications will mean that improve- Time Migration, DOI 10.4043/19875-MS 9, 1060–1068. ments can always be made, which trans- presented at the Offshore Technology Con- Ferguson, J., Klopping, F., Chen, T., Seibert, J., lates into job security for scientists ference, 2–5 May 2011, Houston, Texas. Hare, J., and Brady, J., 2008. The 4D micro- and engineers. JPT Beasley, C., 2008, A new look at marine simul- gravity method for waterflood surveillance: taneous sources, The Leading Edge, Vol- Part 3—4D absolute microgravity surveys Acknowledgements ume 27, Issue 7, pp. 914–917. at Prudhoe Bay, Alaska, Geophysics, Vol. Thanks to Anoop Podor as Imaging White Moldoveanu, N. and Kapoor, J., 2009. What 73, No. 6, pp. WA163-WA171. Paper project coordinator and to Arnis is the next step after WAZ for explora- Vernik, L. and Nur, A., 1992. Ultrasonic Judzis on the SPE R&D Committee for tion in the Gulf of Mexico? SEG Expand- velocity and anisotropy of hydrocarbon bringing this effort together. Thanks ed Abstracts 28, International Exposition source rocks, Geophysics, Vol. 57, No. 5, also to co-chairs in the SPE R&D Sym- and Annual Meeting 41, Houston 2009, pp. 727–735. posium Imaging Session, Carlos Abreu 41–45. http://dx.doi.org/10.1190/1.3255750 Walker, D., 2008, Recent developments in low and Michel Dietrich, along with speak- Krohn, C. and Johnson, M., 2006. HFVSTM: frequency spectral analysis of passive seis- ers Craig Beasley, Wafik Beydoun, Phil- Enhanced data quality through technology mic data, First Break, Vol. 26, 69–78. lipe Doyen, Sergey Fomel, Alex Martinez, integration. Geophysics, v. 71, no. 2, pp. E13– Maxwell, S. and Cipolla, C., 2011. What Does Martin Poitzsch, and Michael Wilt for E23 http://dx.doi.org/10.1190/1.2187730 Microseismicity Tell Us About Hydraulic enlightening presentations. Helpful edits MacBeth, C. and Michelena, R., 2011, Intro- Fracturing? Paper SPE 146932 presented at were made by Kate Baker, Craig Beasley, duction to this special section: Time-lapse the SPE Annual Technical Conference and Len Srnka, Alex Martinez, Sam Perkins, measurements, The Leading Edge, Vol. 30, Exhibition, 30 October–2 November, Den- and Gavin Wall. No. 9, pp. 1006–1007. ver, Colorado.

Jack E. Neal is the strategic technology capabilities. He has published on Society of Exploration Geophysics advisor at ExxonMobil Upstream geology and geophysical integration (SEG) Research Committee. As part Research. He is a member of the SPE in many environments, including the of the committee, she has organized R&D Committee and co-chaired the current SEPM best-seller, Concepts several research workshops and imaging session of the 2011 SPE R&D in Sedimentology and Paleontology given keynote speeches. During her Symposium from which this white #9, “Sequence Stratigraphy of career, she has worked and published paper grew. He has worked globally in Siliciclastic Systems: The ExxonMobil extensively in diverse areas such as research, exploration, development, Methodology”. Neal received a BSc seismic acquisition, receiver coupling, and production assignments with from the University of Tulsa and a rock physics, near surface geophysics, Exxon and ExxonMobil since 1994. PhD. from Rice University in geology crosshole seismic, 3D VSPs, first arrival His current role at ExxonMobil and geophysics. and surface wave tomography, seismic is to interface between research, noise mitigation, vibroseis, and seismic operations and external parties to Christine E. Krohn is a senior research inversion. Krohn received a BSc. from develop technology strategies and associate at ExxonMobil Upstream Emory University and a PhD from communicate differentiating technical Research and the current chair of the University of Texas at Austin in physics.

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