24

Quantitative Hydrogeological Framework Interpretations from Modeling Helicopter Electromagnetic Surveys Data

GPGN 581/681
Student Presentations

Abstract
The Gulf of Mexico (GoM) is one of the most prolific hydrocarbon basins in the world with outstanding source rocks, reservoirs, traps and seals.  However, exploring for giant oil fields in the GoM is fraught with difficulty and risk due to the complex geologic history of the basin.  The complex geology causes major problems for seismic imaging.  The main reasons for the imaging challenges are multifaceted salt geometries with associated rapid and significant velocity contrasts across steep dips.  Unfortunately, in the deepwater GoM, most of the large prospects are at great depths (> 25,000 feet below sea level) and below the salt.  This presentation will show some examples of how BP is dealing with these imaging challenges.

BP has built a leadership position in the GoM with the largest net lease position and highest daily production.  These accomplishments would not have been possible without applying and developing leading edge seismic imaging techniques to help solve the well known imaging issues.  The 1980’s saw 3D seismic and 3D time migration mature; 3D pre-stack depth migration (PSDM) dominated the end of the 90’s, and in the kick-off to the 21st century, BP led the industry into wide azimuth towed streamer (WATS) seismic acquisition technology.  Several recent BP deepwater discoveries were heavily dependent on careful application of 3D PSDM velocity building techniques and various migration algorithms.  The combination of WATS and 3D PSDM has pushed the industry to new levels of imaging capabilities.  BP has successfully utilized this combination for three GoM oil field developments and the 2008 Freedom exploration discovery.

Biography

After studying Geophysics and Business at the University of Utah, Jay Thorseth started his career in the oil and gas industry in 1988 with Amoco in Denver.  During the first part of his career, he worked numerous areas in the US including Alaska, California, North Dakota, Wyoming, Oklahoma and Arkansas with a focus on seismic acquisition, processing and interpretation.  Jay developed an expertise in plays which required pre-stack depth migration and complex seismic imaging.

Jay moved to Houston in 1992 with the hope of securing international exploration positions.  He went on to work in Russia, Azerbaijan and Kazakhstan, where the opportunities for travel and working giant oil prospects were outstanding.  In 1997, Jay moved to Cairo, Egypt for six memorable years exploring for oil in the Gulf of Suez.  Working in integrated teams and utilizing a systematic exploration approach, the department discovered five new oil fields which delivered 130,000 bopd in a very mature basin.  In 2006, Jay returned to Houston to work the Gulf of Mexico, where he is currently the Deepwater Exploration Manager.  BP has continued its excellent exploration track record with recent significant oil discoveries at Kaskida, Isabela, Kodiak and Freedom.  All of these successful exploration prospects required exceptional imaging solutions.

Abstract
For the past several years there have been two sounding radars in orbit around Mars.  One is MARSIS (Mars Advanced Radar for Subsurface and Ionosphere Sounding) on the Mars Express orbiter and the other is SHARAD (Shallow Radar) on the Mars Reconnaissance Orbiter.  SHARAD is designed to study dielectric contrasts associated with geologic layering on fine (10 m) vertical scales and to typically sub-km depths.  SHARAD complements the spatially coarse but deeper sounding of the lower-frequency MARSIS. The depth of exploration of these radars is controlled by the loss properties of the material that the radar waves pass through, with the result that ice-rich material is the most fruitful target for the radars.   The radars have mapped the internal structure of the layered deposits at both poles, revealing details of the layering not observable from surface exposures.  This includes two vertical scales of reflection spacing, which suggest the involvement of two different periodicities of climate forcing.   The radars show that the layered deposits are dominated by ice. An unexpected result is that the substrates beneath deflect very little in response to these loads.  This implies that the elastic lithosphere at the poles is very thick, or the load is not in equilibrium with the viscous mantle, or that martian heat flow has significant spatial variations.  The radars have also mapped subsurface reflections in other areas of Mars, including many locales in the northern lowlands.  Geological evidence points to the possibility of ice-rich deposits at mid-latitudes, relics of past glaciations driven by high rotational obliquities.  The SHARAD radar has confirmed this hypothesis based on the dielectric properties of the associated subsurface materials.

Biography
Professor Phillips is interested in the interior evolution of the terrestrial planets and how a planet's evolution affects and modifies its outer rigid shell or lithosphere through magmatic and tectonic activity. In this research, a variety of geophysical and geological data sets are used in conjunction with computer modeling of physical processes. The underpinning of this activity is application of the concepts of continuum mechanics, with emphasis on computational fluid and solid dynamics, to a variety of geodynamical environments (convection and Stokes flow in viscous fluids, surface and subsurface water flow, elastoviscoplastic deformation of the lithosphere). A variety of approaches are employed, including analytical and numerical methods, and the solid mechanics finite element package MARC©. Professor Emeritus Phillips is retired from Washington University but continues to be active as a scientist at the Southwest Research Institute in Boulder, Colorado.

Abstract
Geophysical inverse problems are ill-posed: the error function has its minimum in a flat elongated valley or surrounded by many local minima. Local optimization methods give unpredictable results if no prior information is available. Traditionally this has generated mistrust on the use of geophysical inverse methods. Stochastic approach of inverse problems
consists in shifting attention to the probability of existence of certain interesting subsurface structures instead of *"looking for the true model"*. Also, inverse problems are ill-conditioned and observed data are noisy. Thus, with no regularization methods (priors) these uncertainties are transmitted to the model parameters by the optimization algorithm. Global optimization methods had become a good alternative to sample efficiently the model space. They are very robust since they don't solve the optimization problem.

In this talk, I will show our research over the last three years on particle swarm optimizers to solve and appraisal inverse problems efficiently. Although PSO is a stochastic algorithm, it can be physically interpreted as a stochastic damped mass-spring system. This analogy served
us to to introduce the PSO continuous model, to deduce a whole family of PSO algorithms, and to give some results of its convergence based on the stochastic stability of the particle trajectories. This makes PSO a very interesting algorithm different from other global algorithms which are purely heuristic. Finally, I will show some applications to low cost methods in hydrogeophysics and Reservoir Engineering (Smart Field Project, Stanford University).

Biography
Juan Luis Fernández Martínez is a Mining Engineer (Oviedo University, 1986), Petroleum Engineer (Institut Francais du Pétrole, 1988) and received his PhD in Geophysical Modeling from the Oviedo School of Mines, 1994. He spent the following year conducting research in geophysical modeling at the Imperial College of Science and Technology (Royal School of Mines, London, 1989). Juan then worked for several years in France as a computer engineer developing different commercial programs for CGG-Petrosystems, IFP, and Schlumberger. In
1994 he joined the Mathematics Department at Oviedo University where he conducts research about inverse problems in environmental geophysics, geostatistical methods, digital treatment techniques (wavelets), and fold modeling. Juan is currently taking a sabbatical year at the University of California, Berkeley, Department of Civil and Environmental Engineering, working with James Rector and Heidi Kuzma on kernel learning methods in geophysical inversion and near surface imaging using passive sources. He is also a visiting professor at UC Berkeley, Lawrence Berkeley National Laboratory and Stanford University, Energy Resources Department, where he is conducting research in several projects concerning the design of a self teaching expert system for tight gas reservoirs (RPSEA project); the solution of different reservoir optimization problems using global algorithms providing an estimation of uncertainty (Smart Field project); and the design of different geostatistical techniques to estimate and simulate spatial random processes at different scales (SCRF consortium).

Abstract

Near surface geophysics has garnered increased attention in recent years in many applications. It is well recognized that near surface is much more dynamic in terms of changing subsurface properties with time due to the proximity of air-earth interface. Not only it is spatially heterogeneous but temporal variations are important for the time-scale of many geophysical experiments. Therefore time-lapse methodology to study subsurface processes is essential if not crucial for many near surface applications. In this talk I will present examples from watershed and environmental problems to discuss the strategies to handle time-lapse data with particular attention to noise and nonlinearity. In second part of the talk I will talk about the role of improved physics in near surface imaging in the context of ground penetrating radar applications. Although it is always desirable to include more physics to explain our data however there is often a sweet spot to choose the appropriate physics depending on the desired scale of the information. I will motivate this aspect using both theoretical and practical examples.

Biography
Partha obtained his B.Sc (Hons) (1991) and M.S. in Exploration Geophysics (1993) from the Indian Institute of Technology, Kharagpur, India and his Ph.D. in 1999 from the University of British Columbia (UBC), Canada with the focus in electromagnetic inversion problems. After a post-doctoral fellowship at the UBC-Geophysical Inversion Facility he joined Conoco Upstream Technology in Oklahoma, USA.  After 3 years of industry experience he joined academia to teach and carry out research in near surface geophysics at Boise State University. Shortly after receiving tenure in 2007 he moved from Boise to Houston and joined the Subsurface Technology of ConocoPhillips where he worked on multi-component seismic and time-lapse.  Currently he is a geophysical research scientist at Upstream  Research Company, ExxonMobil in Houston. His primary interests are in the area of inverse problems, appraisal analysis and its application to a variety of subsurface problems. He is an associate editor of Geophysical Prospecting and was past president of the Near Surface geophysics section of SEG.

Abstract
Rulison Field is a basin-centered gas accumulation located in the Piceance Basin, NW Colorado. The reservoir consists of lenticular fluvial sands, shales, and coals of the Upper Cretaceous Williams Fork Formation. Typical sand body thickness are 10-15 ft, an order of magnitude lower than the seismic resolution which is 105 ft.
The sandstone reservoirs are the primary target and are typically low porosities (6-10 %) and very low permeabilities (1-2 microD). The best production is dependent on the fracture permeability. The major objectives of the reservoir characterization in Rulison are (1) the imaging of the lenticular sand bodies, (2) the identification of the best overpressured productive sandstones, and (3) the determination of the fractured intervals. To achieve these goals, a quantification of anisotropy in the reservoir is essential in order to understand the seismic amplitude responses.

Assuming vertical transverse isotropy, the Thomsen anisotropy parameters are estimated in the UMV Shale (top of the gas-saturated section) from a joint PP/PS traveltime inversion using exclusively surface seismic data. A synthetic AVO study based on the elastic parameters extracted at the study well location and on the Thomsen parameters shows that the reflection coefficients in the VTI over HTI model of the upper reservoir can be approximated by the small-offset reflection coefficients in isotropic media. This approximation holds for offsets less than 7,000 ft and 5,000 ft for compressional- and converted-waves respectively. Using a poststack isotropic converted-wave amplitude inversion, pseudo-S-impedance volumes are generated and nine gas-bearing lenticular fluvial sand bodies are imaged in the vicinity of the study well location with a vertical resolution of 35-50 ft and a lateral extent of 500-1,000 ft. The good quality overpressured sand bodies are identified thanks to high resolution Vp/Vs volumes. The high fracture density intervals are determined from the effects of shear-wave splitting on converted-wave reflectivity.

Biography
Alexandre Araman obtained his MSc in Electrical Engineering from the Ecole Nationale Supérieure des Télécommunication (Paris) and MSc in Signal Processing from the Imperial College (London). His research topics were related to image and speech processing and to the implementation of stochastic methods for signal processing. He joined the seismic processing group in TOTAL in 2007 and worked on the implementation and testing of the virtual source method on synthetic and field data. In 2008, Alexandre joined the Colorado School of Mines to pursue his graduate studies in geophysics. His research is focused on the inversion of multicomponent seismic data for reservoir characterization.

Abstract
BHP Billiton exploration and appraisal efforts in the deep water Gulf of Mexico relies on integrating many new technologies associated with all disciplines to be a successful operator. In the initial phases of exploration and field appraisal, it is extremely important to get the best seismic data possible for a better understanding of the subsurface geology. With sub-salt targets, it is imperative to have seismic data with an adequate distribution of multi-azimuth and offset attributes for proper illumination and subsequent migration. In addition, understanding the depositional turbidite sand reservoir system beneath these salt bodies is also fundamental to reducing the risks. This presentation provides two examples of how these types of technologies
impact BHP Billiton's methods to explore and appraise in this challenging subsurface environment.

Recent efforts to deal with illumination problems inherent in narrow azimuth marine seismic have included using ocean bottom sensors or conventional streamers. The streamer methods include wide-azimuth methods using multiple vessels (WATS) and multi-azimuth methods that
only require a single vessel. The SMAART (SMAART JV, Paffenholz, et.al, 2002), Helix (Texaco, Sukup, 2002) and WATS (BP, Threadgold, et.al, 2006) methods are examples of wide-azimuth and give more uniform azimuth distribution. The Varg survey (PGS, 2005) acquired as several narrow azimuth surveys is an example of multi-azimuth, which has operational advantages. Using these types of acquisition methods have been proven efficient for pre-drill projects or for those projects with very little surface infrastructures. Howard, et.al(BHP Billiton, 2004) generalized these methods and suggested that the advantages of both can be captured using hybrid methods, which has been referred to as rich-azimuth (RAZ). By combining multi-azimuth and wide-azimuth acquisition methods, BHP Billiton has designed a RAZ survey for a sub-salt illumination problem at the Shenzi field in the deep water domain of the Gulf of Mexico. The design has operational advantages specifically associated with post-discovery seismic surveys necessary for field appraisal where surface facilities and drilling vessels pose logistical challenges.

A two-dimensional computational model for high-resolution simulations of turbidity currents is presented. Physical results that focus on the influence of particle entrainment from the underlying bed are considered. As turbulence motions detach particles from the bottom surface, re-suspended particles entrained over the entire current length are transferred to the current head, causing it to become denser and to accelerate. The conditions under which turbidity currents may become self-sustaining through particle entrainment are investigated as a
function of slope angle, particle concentration and particle size.

Biography
Dean graduated from Colorado School of Mines in 1975 with a BS in
Mathematical Engineering and subsequently obtained his MS from CSM in Geophysical Engineering in 1978. He has been an Petroleum Industry
Geophysicist for 35 years and has worked in numerous exploration and
appraisal roles both in the domestic and international arenas. His domestic industry experience included an initial stint with Amoco Production in Denver followed by working for a number of independent oil companies as well as Union Texas Petroleum. In 1991, Dean hired on with Hamiliton Oil / BHP in Denver and was subsequently moved to London, England where he concentrated on exploration and field appraisal in Russia and Former Soviet Union countries. In addition, he contributed to North Sea and Irish Sea appraisal projects. After moving back to Houston in 1995 he began work for BHP Billiton in the deep water domain of the Gulf of Mexico. His efforts included exploration and field appraisal associated with sub-salt prospects, many of which are very large and giant producing oil fields today. His Houston based BHPB endeavors included technical roles in new venture exploration, prospect development, field appraisal throughout the world as well as a member of the industry joint venture, SMAART Applied Research Program. His efforts in this research program that investigated seismic multiple attenuation, seismic modeling studies and derivations of new multi-azimuth streamer acquisition methods led to the 2008 SEG Distinguished Achievement Award. His interpretational experience includes structural and seismic attribute analyses with an emphasis of applying cutting edge technologies in seismic data acquisition, processing and depth imaging. Dean is currently working as an Geophysical Advisor with BHP Billiton in Houston, Texas.

Abstract
The most common parameters measurable in seismology are VP and VS, being the propagation velocities of compressional P-waves and shear S-waves in elastic media. However, these measured quantities are composed of the more fundamental rock parameters of density and two moduli termed lambda and mu, introduced and named after the 18th century French engineer, mathematician, and elastician Gabriel Lamé. Lamé also formulated the modern version of Hooke’s law relating stress to strain in its general tensor form, thereby creating the basis for the science of materials, including rocks. Interestingly and most notably, only Lamé’s moduli lambda and mu appear in Hooke’s law and not Young’s modulus, the bulk modulus, or any other common modulus.

The application of seismology to measure or describe rocks and fluids is based on the physics used to derive propagation velocity that originates with the elastic wave equations. These wave equations equate Hooke’s law, providing the Lamé moduli, to Newton’s second law that provides density and their solutions form the basis for AVO used to describe attributes of the propagating medium. The result gives relations between propagation velocity VP and VS and the intuitively simple Lamé moduli of incompressibility, lambda, and rigidity, mu. Consequently lambda and mu afford the most fundamental and orthogonal parameterization of elastic seismic waves to extract information about rocks within the Earth.

The historical development of seismology at widely different scales has led to the use of a large and confusing array of parameters, which are usually complicated functions of the Lamé moduli. This includes Poisson’s ratio, Young’s and the bulk modulus, as well as standard AVO attributes such as intercept and gradient, that arise as a result of the media’s form and its measurement environment. For example, the same rock will deform volumetrically as a function of the bulk modulus, or longitudinally as a function of Young’s modulus, or as a function of the nameless P-wave propagation modulus (lambda + 2mu) in the Earth. Extracting the Lamé moduli from these mixed parameters provides insight into their physical meaning, because Lamé moduli are intrinsic and invariant properties of elastic media. Examples of this from the fields of earthquake seismology, AVO, and passive microseismology will be presented.

Biography
Bill Goodway obtained a B.Sc. in geology from the University of London in 1977 and a M.Sc. in geophysics from the University of Calgary in 2001. Prior to 1985, Bill worked for various seismic contractors in the United Kingdom and Canada. Since 1985, Bill has been employed at PanCanadian Petroleum within the Geophysics department in various capacities from geophysicist to being the team lead of a seismic analysis group. Following the PanCanadian and AEC merger to form EnCana in 2002, Bill has worked in the Frontier and New Ventures Group and more recently in Canadian Ventures and Gas Shales, as an adviser for seismic analysis. In this position, Bill is involved in virtually all aspects of applied seismic exploration from acquisition design and processing to experimental special projects and new interpretation methods.

He has presented and coauthored a number of papers at CSEG, EAGE, and SEG conventions and research workshops on seismic acquisition and processing, borehole geophysics, anisotropy, multicomponent recording, and AVO. Bill received CSEG’s annual Best Paper Award both in 1994 and 1997, the CSEG convention Best General Paper award in 1996, and the CSEG convention Best Technical Paper award in 1997. In 2008, Bill was the recipient of the CSEG Medal, the Society’s highest award.

He is a member of CSEG, SEG, EAGE and APEGGA as well as the SEG Research Committee. In addition, Bill was elected vice president and president of the CSEG for the 2002/2003 term.

Abstract

The need for allocation and management of water resources within the state of Nebraska has created a demand for innovative approaches to data collection for development of hydrogeologic frameworks to be used for two and three dimensional groundwater models.  In 2008 the USGS in cooperation with the North Platte Natural Resources District, South Platte Natural Resources District and the University of Nebraska Conservation and Survey Division began using helicopter (frequency domain) electromagnetic (HFEM) surveys to map selected sections of the Nebraska Panhandle. The surveys took place in selected sections of the North Platte River valley, Lodgepole Creek and portions of the adjacent tablelands. The objective of the surveys is to map the aquifers of the area to improve understanding of the groundwater-surface water relationships and improve hydrogeologic frameworks used in improving the three dimensional accuracy of the groundwater models of the area. For the HFEM method to have an impact in a groundwater model at the basin scale, hydrostratigraphic units need to have detectable physical property (electrical resistivity) contrasts.  When these contrasts exist within the study area and they are detectable from an airborne platform large survey areas can be used to rapidly generate two and three dimensional maps and models of hydrogeologic features.  To make the geophysical data useful to multidimensional groundwater models, numerical inversion is necessary to produce a depth dependent physical property data set reflecting hydrogeologic features.  These maps and depth images of electrical resistivity in themselves are not useful for the hydrogeologist.  They need to be turned into maps and depth images of the hydrostratigraphic units and hydrogeologic features. Through a process of numerical imaging, inversion, sensitivity analysis, geological ground truthing (boreholes), geological interpretation, hydrogeologic features are characterized.  Resistivity depth sections produced from this process are used to pick contacts between hydrostratigraphic units. This provides a three dimensional image of the hydrostratigraphic units associated with the electrical resistivity derived from the HFEM with associated statistical confidences on the picked contacts. The interpreted two and three dimensional data provides the groundwater modeler with a high-resolution hydrogeologic framework and a solid understanding of the uncertainty in the information it provides. This interpretation facilitates more informed modeling decisions, more accurate groundwater models and development of more effective water-resources management strategies.

Biography
Mr. Jared D. Abraham is a GS-14 Operational Geophysicist with the U.S. Geological Survey, Crustal Imaging and Characterization Team. He has been with the US Geological Survey for 13 years and was a geophysicist with the Department of Energy contractor Geotech Inc. at the Grand Junction Project Office for four years.  Prior to his entering public service he was a geophysical technician with Northern Geophysical a seismic acquisition company. His work has focused on the application of geophysical techniques for mapping mineral, energy, and water resources as well as engineering and environmental problems.  Research focus includes the use of airborne geophysical survey techniques to construct 3-D geological and hydrological framework models for the application of resource management.  This includes magnetic, radiometric, gravity, gravity gradiometer, and electromagnetic techniques.  He is also working on the application of Nuclear Magnetic Resonance measurements for groundwater exploration.  He has worked extensively throughout the world conducting airborne and ground geophysical surveys including North America, Europe, Antarctica, Africa, the Middle East and Central Asia.  He has served as a technical expert for many US Government Agencies including the Department of State, Department of Defense, Department of Interior, Department of Agriculture as well as many state and local government organizations. Mr. Abraham received his Masters in Science in Geophysics from the Colorado School of Mines in 1999. He received his Baccalaureate in Science in Geology from Mesa State College in 1994 after concluding a research internship with the University of Alaska Fairbanks, Geophysical Institute.

Abstract
Microseismic methods for hydraulic fracture detection have been of widespread use in the oil and gas industry since the mid-1990’s.  The Reservoir Characterization Project’s Phase XII, an integrated study focusing on dynamic characterization of a Morrow sandstone incised valley-fill reservoir, presents a unique opportunity to apply this technology to tertiary production and sequestration processes.  I present a new microseismic technique which identifies areas of fluid flow within the Upper Morrow reservoir of Postle field, Oklahoma, and integrate the results of this process with 3D seismic and reservoir models to interpret areas of CO2 flow within the formation.  Illumination of fluid flow areas within and around the target injection interval can help maximize both current and future injection and sequestration efforts.

Biography
Andrew grew up in the suburbs of Oakland, CA. and graduated from the University of California at Davis in 2006 with a B.S. in geology. In his spare time, he enjoys spending time with friends and family, watching football, and stopping in for a pint at the local dive. He recently moved to Houston where he has taken a position with BP on a natural gas exploration team..

Abstract

A permeability model is being developed for Postle Field. The area of study is located in Texas County, Oklahoma. The biggest challenge at Postle Field is the heterogeneity within the reservoir, especially the presence of high permeability zones interpreted as a basal lag and its repercussions in terms of field performance under a CO2 injection framework. Core data are available in the study area. In these data sandstone petrofacies within the reservoir can be identified and distinguished by the use of petrophysical attributes from the logs. We perform a multiclass classification using Support Vector Machines (SVM) to breakdown the Morrow A sandstone into sandstone petrofacies with characteristic permeability distributions to be used as input to a permeability model. We obtained  a permeability model that honors the geology and predicts permeability based on permeability distributions linked to the different facies interpreted in the area.

Biography

Cucha was born in Anzoátegui state, Venezuela. Because her father worked in the oil industry, Cucha was raised in "oil towns", living in 7 of the 24 states in Venezuela. Her first field trip was in kindergarden, visiting oil seeps! Cucha earned her bachelor's degree at Simón Bolívar University in 2005 and worked in Canada with Schlumberger during 2005-2006. She returned to Venezuela and worked for P&G. In spring 2008 she joined CSM as a master’s student in RCP.

Abstract

Electrical field bursts are passively observed when a non-wetting fluid displaces a wetting fluid in a porous material (drainage) as well as during imbibition experiments. Sandbox and Helle-Shaw Cell experiments were conducted with various sized glass beads to study these electrical disturbances using a network of very sensitive non-polarizing electrodes located in relevant locations within the experiment set-ups.  Drainage exhibits many more electrical bursts, with a higher magnitude, than imbibition.  These events are only observed during drainage or imbibition, not prior to or after the water is flowing inside the porous material.  We point out the possible relationship between the formation of Haines Jumps and the occurrence of these electrical bursts.  These bursts show a power law distribution during drainage with a power law exponent averaging about -1.83± 0.25 among the experiments described herein, in agreement with previously published studies using pressure, acoustic, and hydro-acoustic events.  Imbibition does not display the same power law relationship. The best fit for the mean exponent of the power law relationship for the imbibition tests is an exponent of -1.24 ± 0.22.  These new observations could be used to develop a new methodology to use acoustic signals and electrical bursts to monitor two-phase flow in porous rocks.

Biography

Allan Haas started his career as an electrical engineer and has worked in the aerospace and astronomy communities for many years making contributions in a variety of notable projects.  Work involved research into fiber-optic sensor systems, sonar, borehole seismology instrumentation, and astronomical imaging detector development.  The most prominent aerospace work involved high profile spacecraft instrumentation projects such as the Hubble Space Telescope, the Deep Impact Mission to Comet Tempel 1, and the New Horizons Mission to Pluto and the Kuiper Belt and beyond.  The Hubble Space Telescope work involved the project management of the development of the Wide Field Camera 3 Near Infrared image detector first phase of development including detector material design and fabrication, detector packaging, and integrated circuit design and fabrication.  The Deep Impact efforts involved the design of the packaging of the Infrared Imaging Spectrometer detector used to measure the infrared spectrum of the impact of the Smart, Instrumented Impactor into Comet Tempel 1.  The New Horizons efforts involved the packaging of the New Horizons Near Infrared Imaging Spectrometer detector for the Ralph instrument. 

Interest in geophysics was developed through an effort to develop borehole acoustic sensor systems.  In conjunction with Paulsson Geophysical Services Inc. performed a cross-well test of a US Navy sonar system in a benign test borehole at the Chevron Technology Research Center in La Habra, CA in 1995.  This test used a prototype borehole seismic source that was fabricated through a consortium with Paulsson Geophysical Inc., Sandia National Laboratories, Chevron and more.  This was the first time a 48 channel hydrophone array had been tested in a borehole environment.  This work resulted in a paper being presented at the Society of Exploration Geophysicists meeting in 1996 describing the results of these tests and presenting imbedded instrumentation concepts for real time reservoir management.  Geophysics has been my main interest ever since then.