`
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`
`
`IN THE UNITED STATES PATENT & TRADEMARK OFFICE
`______________________
`
`BEFORE THE PATENT TRIAL AND APPEAL BOARD
`______________________
`
`WESTERNGECO L.L.C.,
`Petitioner,
`
`v.
`
`PGS GEOPHYSICAL AS,
`Patent Owner.
`______________________
`
`Case IPR2015-00309
`Patent U.S. 6,906,981
`______________________
`
`
`DECLARATION OF LUC T. IKELLE IN SUPPORT OF
`
`PETITION FOR INTER PARTES REVIEW OF
`
`U.S. PATENT NO. 6,906,981
`
`UNDER 37 C.F.R. § 1.68
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`
`
`
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`WesternGeco Ex. 1002, pg. 1
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`
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`
`
`I.
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`II.
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`TABLE OF CONTENTS
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`Page
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`INTRODUCTION ....................................................................................................... 1
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`BACKGROUND AND QUALIFICATIONS ....................................................... 2
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`III. UNDERSTANDING OF PATENT LAW ............................................................. 7
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`IV. BACKGROUND .......................................................................................................... 9
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`A.
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`B.
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`C.
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`Background of the Field Relevant to the ‘981 Patent .................................. 9
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`Summary of the ‘981 Patent ........................................................................... 15
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`Summary of the Prosecution History ........................................................... 20
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`V.
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`LEVEL OF ORDINARY SKILL IN THE PERTINENT ART ...................... 24
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`VI. BROADEST REASONABLE INTERPRETATION ......................................... 25
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`VII. DETAILED UNPATENTABILITY ANALYSIS ............................................... 26
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`A.
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`B.
`
`C.
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`Claims 1, 2, 7, 10-21, 23, 24, 30-32, and 36-38 are Anticipated by
`De Kok .............................................................................................................. 27
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`Claims 1-38 are Rendered Obvious by Beasley in view of
`Timoshin ........................................................................................................... 45
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`Claims 1-38 are Rendered Obvious by Beasley in view of
`Edington ............................................................................................................ 72
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`VIII. CONCLUSION ........................................................................................................... 97
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`i
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`WesternGeco Ex. 1002, pg. 2
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`
`
`Declaration of Luc T. Ikelle in Support of Petition for Inter Partes Review of U.S.
`Patent No. 6,906,981
`I, Luc T. Ikelle, do hereby declare as follows:
`
`I.
`1.
`
`INTRODUCTION
`
`I have been retained as an expert witness on behalf of WesternGeco L.L.C
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`(“WesternGeco”) for the above-captioned Petition for Inter Partes Review
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`(“IPR”) of U.S. Patent No. 6,906,981 (“the ‘981 Patent”). I am being
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`compensated for my time in connection with this IPR at my standard
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`consulting rate of $400 per hour. My compensation is not affected by the
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`outcome of this matter.
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`2.
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`I have been asked to provide my opinions regarding whether Claims 1-38 of
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`the ‘981 Patent are unpatentable as anticipated or would have been obvious to
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`a person having ordinary skill in the art at the time of the alleged invention.
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`The ‘981 Patent issued on June 14, 2005 from U.S. Patent Appl. No.
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`10/197,235 (“the ‘235 Application”), filed on July 17, 2002. (Ex. 1001)
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`In preparing this Declaration, I have reviewed the ‘981 Patent, the file history
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`of the ‘981 Patent, numerous prior art references, and technical references from
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`3.
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`4.
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`the time of the alleged invention.
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`5.
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`I understand that claims in an IPR are given their broadest reasonable
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`interpretation in view of the patent specification and the understandings of one
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`having ordinary skill in the relevant art.
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`In forming my opinions expressed in this Declaration, I relied upon my
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`education and experience in the relevant field of art, and have considered the
`1
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`6.
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`WesternGeco Ex. 1002, pg. 3
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`Declaration of Luc T. Ikelle in Support of Petition for Inter Partes Review of U.S.
`Patent No. 6,906,981
`viewpoint of a person having ordinary skill in the relevant art, as of the earliest
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`alleged priority date, July 17, 2002. I have also read and considered the ‘981
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`patent and its prosecution history, the exhibits listed in the Exhibit List filed
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`with the ‘981 petition, as well as any other material referenced herein.
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`II. BACKGROUND AND QUALIFICATIONS
`7.
`I am an expert in the field of seismic data acquisition and seismic data
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`processing, and have been an expert in the fields since prior to 1986. In
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`formulating my opinions, I have relied upon my training, knowledge, and
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`experience in the relevant art. A copy of my curriculum vitae is provided as
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`Appendix A to this Declaration and provides a comprehensive description of
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`my relevant experience,
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`including academic and employment history,
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`publications, participation in professional societies, and issued and pending
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`U.S. patents.
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`8.
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`I received a M.Sc. (1982) in Mathematics and Theoretical Physics from Paris
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`Diderot University, followed by a Ph.D. in Geophysics (1986), from the same
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`university. Paris Diderot University is known as one of the preeminent schools
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`for science and mathematics in France. Paris Diderot University is home to
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`one of the campuses of the Institut de Physique du Globe de Paris (IPGP),
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`where I took many graduate classes. IPGP is known as one of the top schools
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`for geophysics in the world, most famous for contributions to inverse problem
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`theory and the development of plate tectonics theory.
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`WesternGeco Ex. 1002, pg. 4
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`Declaration of Luc T. Ikelle in Support of Petition for Inter Partes Review of U.S.
`Patent No. 6,906,981
`9.
`In 1986, my Ph.D. thesis “A multidimensional linearized inversion of seismic
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`data” received the Le Prix de These du CNRS which is a yearly award given for
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`the best Ph.D. thesis in France on the subject of earth and space sciences.
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`10. After receiving my Ph.D., I did post-doctoral research at Cray Research, Inc.
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`Cray Research played an important role in making supercomputers a reality.
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`Because supercomputers are virtually necessary to enable 3D seismic surveying,
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`the oil and gas industry was an early adopter of the technology. I focused my
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`work on developing 3D seismic inversion algorithms for use with the Cray Y-
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`MP supercomputer. Seismic inversion involves the characterization of
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`geological formations using reflection data.
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`11.
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`In 1988, I began working as a research scientist at Schlumberger Geco-Prakla,
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`Schlumberger Doll Research, and Schlumberger Cambridge Research.
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`Schlumberger Ltd.
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`is
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`the world’s
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`largest oilfield services company.
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`Schlumberger owns a number of research centers which study and develop
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`technologies related to seismic acquisition and data processing, as well as many
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`other topics. As a research scientist, I helped develop three commercial
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`products for Schlumberger: (i) a migration-velocity analysis tool called PFKIM
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`(1989), (ii) anisotropic tools for migration, AVAZ analysis, and model-building
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`(1992), and (iii) a multiple-attenuation technique called ISMA (1995). I worked
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`as a research scientist until 1997.
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`3
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`WesternGeco Ex. 1002, pg. 5
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`Declaration of Luc T. Ikelle in Support of Petition for Inter Partes Review of U.S.
`Patent No. 6,906,981
`12. My academic career began in 1997 when I served as an Associate Professor in
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`the Department of Geology and Geophysics at Texas A&M University. I
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`worked as an Associate Professor until 2001, when I became the Robert R.
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`Berg Professor in the Department of Geology and Geophysics at Texas A&M
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`University. I continue to hold the Robert R. Berg Professorship at Texas
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`A&M, though I have been on sabbatical since early 2013. I teach several
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`classes on subjects such as petroleum seismology, signal processing, and
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`numerical modeling. As a professor, I have supervised over forty Master’s and
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`Ph.D. students in geophysics and petroleum engineering. I also supervised
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`three post-doctorates, one that is now a professor at Beijing University and two
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`others working in the geophysical exploration industry.
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`13. While a professor at Texas A&M, I also served as the director of the
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`Consortium on Automated Seismic Processing (CASP) at the university. The
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`consortium spearheaded research to develop an automated seismic data
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`processing system that could extend the seismic resolution window. As the
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`director of CASP, I helped develop the idea of using multiple near-
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`simultaneously fired sources to acquire seismic data. CASP actually coined the
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`term “multishooting” to refer to this concept, though it is now commonly
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`referred to as “simultaneous shooting.” The consortium has also produced
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`important research results related to the optimization of multiple attenuation
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`methods and use of higher order statistics for seismic imaging.
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`Declaration of Luc T. Ikelle in Support of Petition for Inter Partes Review of U.S.
`Patent No. 6,906,981
`14. During my current sabbatical, I have founded and developed a geophysical
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`consulting company called Imode Research. The company aims to assist
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`geophysical exploration companies with data analysis and provide intensive
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`courses and consultancy on topics related to petroleum seismology. These
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`courses help keep scientists and engineers in the field of petroleum seismology
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`current on new developments and techniques in the field. The company has
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`worked to develop advanced software to facilitate seismic data processing.
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`15. Throughout my career, I have been involved in numerous advisory groups for
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`oil and gas exploration organizations. Furthermore, in 2006, I was selected to
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`be on the Ultra-Deepwater Advisory Committee which advises the Secretary of
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`Energy on topics related to ultra-deepwater natural gas and petroleum
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`exploration and production. I served on that committee until 2013.
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`16.
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`I am a member of several professional societies related to geophysics and
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`marine seismology, including the Society of Exploration Geophysicists (SEG),
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`the American Geophysical Union (AGU), the American Physical Society (APS),
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`and the European Association of Geoscientists and Engineers (EAGE). In
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`addition, I serve as a member of the editorial board of the Journal of Seismic
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`Exploration.
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`17. Over my career, I have edited or authored several books and published over
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`one hundred technical articles and papers in international journals on topics
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`related to geophysics and seismology. Many of those publications focus
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`Declaration of Luc T. Ikelle in Support of Petition for Inter Partes Review of U.S.
`Patent No. 6,906,981
`directly on marine seismology. I have also presented many papers at technical
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`conferences including at SEG Annual Meetings. For example, in 2000, I
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`presented my paper “Multishooting method for simulating seismic surveys:
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`Application to 3-D finite-difference modeling” during the Technical Program
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`of the 2000 SEG Annual Meeting in Calgary. The “multishooting” concept
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`disclosed and discussed in my paper was equivalent to the concept of using
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`“multiple seismic sources” discussed in the ‘981 Patent. I worked on
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`developing the concept of multishooting because I understood that there could
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`be significant savings in time and money in seismic data acquisition if multiple
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`sources were activated simultaneously or near-simultaneously. However, the
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`software used to process seismic data is only able to handle “single-shot data”
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`and not “multishot” data which contain interfering reflections from multiple
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`sources. Thus, I became interested in developing “decoding” methods to
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`convert multishot data to single-shot data so it could be processed with the
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`existing software.
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`18.
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`Introduction to Petroleum Seismology, a book I co-authored, was published in
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`2005. Introduction to Petroleum Seismology went on to become a best-selling
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`SEG publication and is widely used in geophysics classes in advanced
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`undergraduate classes and graduate classes. Another book I authored, Coding
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`and Decoding: Multiple Access Technology in Seismology and the Concept of
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`Multishooting, was published in 2009. To my knowledge, this is the only book
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`Declaration of Luc T. Ikelle in Support of Petition for Inter Partes Review of U.S.
`Patent No. 6,906,981
`that has been published specifically on the topic of multishooting, or
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`“simultaneous shooting.” I also have a new book coming out in early 2015, the
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`second edition of Introduction to Petroleum Seismology which will include two
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`chapters on multishooting, covering over two hundred pages.
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`19.
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` I am also a named inventor on six U.S. patents related to seismic data
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`acquisition, processing, and imaging. The first, entitled “Source signature
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`determination and multiple reflection reduction” was filed in 1995. And my
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`most recent patent, entitled “Scattering diagrams in seismic imaging” was
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`granted in 2008.
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`III. UNDERSTANDING OF PATENT LAW
`20.
`I understand that prior art to the ‘981 Patent include at least patents and
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`printed publications in the relevant art that predate July 17, 2002, the filing date
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`of the ‘981 Patent.
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`21.
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`I understand that a claim is unpatentable if it is anticipated. Anticipation of a
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`claim requires that every element of a claim be disclosed expressly or inherently
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`in a single prior art reference, arranged in the prior reference as arranged in the
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`claim.
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`22.
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`I understand that a claim is unpatentable if it is obvious. Obviousness of a
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`claim requires that the claim would have been obvious from the perspective of
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`a person having ordinary skill in the relevant art at the time the alleged
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`invention was made. I understand that a claim may be obvious from a
`7
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`WesternGeco Ex. 1002, pg. 9
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`Patent No. 6,906,981
`combination of two or more examples from a single prior art reference or two
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`or more prior art references.
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`23.
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`I understand that an obviousness analysis requires an understanding of the
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`scope and content of the prior art, any differences between the claims of the
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`patent in question and the prior art, and the level of ordinary skill in evaluating
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`the pertinent art.
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`24.
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`I further understand that certain factors may support or rebut the obviousness
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`of a claim. I understand that such secondary considerations include, among
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`other things, commercial success of the patented invention, skepticism of those
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`having ordinary skill in the art at the time of the invention, unexpected results
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`of the invention, any long-felt but unsolved need in the art that was satisfied by
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`the invention, the failure of others to make the invention, praise of the
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`invention by those having ordinary skill in the art, and copying of the invention
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`by others in the field. I understand that there must be a nexus—a
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`connection—between any such secondary considerations and the claimed
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`invention. I also understand that contemporaneous and independent invention
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`by others is a secondary consideration tending to show obviousness.
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`25.
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`I further understand that a claim is obvious if it unites old elements with no
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`change to their respective functions, or alters prior art by mere substitution of
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`one element for another known in the field and that combination yields no
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`more than predictable results. While it may be helpful to identify a reason or
`8
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`WesternGeco Ex. 1002, pg. 10
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`Declaration of Luc T. Ikelle in Support of Petition for Inter Partes Review of U.S.
`Patent No. 6,906,981
`motivation for this combination, common sense should guide and no rigid
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`requirement of finding a teaching, suggestion, or motivation to combine is
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`required. When a product is available, design incentives and other market
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`forces can prompt variations of it, either in the same field or a different one. If
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`a person having ordinary skill in the relevant art can implement a predictable
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`variation, it is more likely to be obvious. For the same reason, if a technique
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`has been used to improve one device and a person having ordinary skill in the
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`art recognizes that it would improve similar devices in the same way, using the
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`technique is obvious. I understand that a claim may be obvious if common
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`sense directs one of ordinary skill in the art to combine multiple prior art
`
`references or add missing features to reproduce the alleged inventions recited
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`in the claims.
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`IV. BACKGROUND
`A.
`Background of the Field Relevant to the ‘981 Patent
`26. The ‘981 Patent “relates generally to the field of seismic exploration.” (Ex.
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`1001 at 1:17-18). The field of seismic exploration involves the mapping of
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`geological formations using acoustic or elastic waves. During a seismic survey,
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`sources of acoustic energy, including vibrators and air guns, are activated to
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`generate waves that travel through geological formations. Those waves
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`generated from the sources reflect off the geological formations they come into
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`contact with, creating reflected waves which are recorded by sensors, including
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`9
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`WesternGeco Ex. 1002, pg. 11
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`Patent No. 6,906,981
`geophones and hydrophones. The reflection data are processed and analyzed
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`to provide information about the geological formations.
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`27. One of the primary reasons for conducting seismic surveys is to find and
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`enhance production from oil reserves. So one of the reasons land surveying
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`and marine surveying were developed was to seek out oil reserves in both
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`environments. The high-level principles underlying seismic surveying described
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`in ¶ 26 are the same for both the land and marine contexts.
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`28. The land and marine contexts have a number of similarities. For example, they
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`present some of the same challenges and some of the same solutions can be
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`adopted to meet those challenges. This is often because the high-level goal of
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`acquiring the highest quality data at the least possible cost is common to both
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`contexts. As such, there has been a long history of taking solutions developed
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`in the land context and implementing it in the marine context, or vice versa.
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`Even if a technique is not directly adapted from context to another, it is also
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`very common for techniques to be developed for use in both contexts.
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`29.
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`For example, multicomponent seismic data acquisition began in the land
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`context and has now been adopted in the marine context. (Ex. 1009 at 161,
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`Ex. 1010 at 477-78). Multicomponent acquisition was developed to provide
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`access to measurements of shear waves, or S-waves,
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`in addition to
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`compressional waves, or P-waves. Conventional seismic surveys only record P-
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`waves. The S-wave data helps indicates where fluids and hydrocarbons are
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`Patent No. 6,906,981
`because there are no shear waves in a fluid. Multicomponent acquisition was
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`later adapted to the marine context for use in ocean-bottom acquisition for the
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`same purposes described above. Furthermore, more recently, multicomponent
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`acquisition has been used in towed-streamer surveys to help “deghost” data,
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`improving data resolution. “Deghosting” data refers to removing the
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`interference caused by the reflection of the energy from a seismic source from
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`the sea surface.
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`30. One example of a technique used in both the land and marine contexts is the
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`common midpoint gather, or CMP gather. The CMP gather has become an
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`important part of conventional seismic surveying in both the land and marine
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`contexts since the 1960s. A CMP gather is essentially a collection of all the
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`data with respect to a particular subsurface location. More specifically, a CMP
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`gather constitutes all the traces for which the midpoint between a given source
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`and receiver is the same, which correspond to the same set of reflections being
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`detected. (Ex. 1008 at 86). When all the data sampling one subsurface location
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`is collected, it can be “stacked” to improve the signal to noise ratio, providing
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`better data. (Ex. 1008 at 86). The following figure shows the common
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`midpoint between several source-receiver pairs:
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`
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`31. The transferability of a technology from the land context to the marine context,
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`or vice versa, depends on the specific nature of the technology and the
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`problem being addressed.
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`32. The ‘981 Patent relates more specifically to the concept of “simultaneous
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`shooting” in which multiple sources are fired simultaneously or near-
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`simultaneously. Simultaneous shooting can save survey time and money by
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`improving seismic data acquisition efficiency. (Ex. 1011 at 1). A result of
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`simultaneous shooting is that the recorded data contains interference because
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`the shots overlap. Current data-processing techniques assume that input data
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`comes from single shots, with no overlap. Thus, the data resulting from
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`simultaneous shooting must be separated (decoded) in order to eliminate
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`interferences between single shots. Without decoding, no meaningful
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`information can be extracted from the multishot data using current data-
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`
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`processing techniques. The figure below shows the steps involved in
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`“simultaneous shooting”.
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`33. Because of the increased efficiency of seismic data acquisition and processing,
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`
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`efforts to develop simultaneous shooting (or “multishooting”) techniques in
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`both the land and marine contexts have been ongoing for nearly two decades.
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`(Ex. 1011 at 1). In fact, the central problem that simultaneous shooting
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`introduces and attempts to solve is related to the “cocktail party problem”
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`defined in the 1950s. The idea is that even at a loud cocktail party, one is able
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`to focus on a particular conversation and ignore the “noise” or “interference”
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`from other nearby conversations. Ignoring or filtering out interference has
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`been a classic challenge in fields including seismic exploration, speech
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`recognition, and medical imaging. The figure below, from my book (Ex. 1012
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`at 45-47) illustrates the cocktail party problem. If numerous people speak
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`(generate voice signals) at the same time in a room with two microphones, the
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`output of each microphone will be a mixture of the voice signals. The goal is
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`to decode the outputs of each microphone in order to recover the original
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`voice signals.
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`
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`34. Various methods of encoding source signatures have been used to facilitate
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`separation of shots gathered via simultaneous shooting. “Encoding” in this
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`context refers to a way to distinguish signals. “Source signature” refers to the
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`pulse which describe the magnitude, the duration, and overall time dependency
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`of a source. Encoding multiple source signatures allows us to distinguish the
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`shots from a given source so they can be identified to that source. There are
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`multiple types of encoding which have been used in both the land and marine
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`contexts since before the filing date of the ‘981 Patent. (Ex. 1013 at 1389).
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`Encoding can include varying the amplitude, frequency, and/or firing time of
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`the source signature.
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`Patent No. 6,906,981
`35. Time delay is a typical example of source encoding used in seismic surveys. It
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`consists of introducing a time delay between the firing times of the single shots.
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`The time delays are predetermined and known. These values are used in the
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`decoding process to reconstruct the data from shots of one source by shifting
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`the time delay so that all the events corresponding to this source are “in-
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`phase.” The events corresponding to other shots are “out-of-phase.” In some
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`methods of time encoding, the data that is in-phase can be distinguished from
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`the data that is out-of-phase in order to identify the data originating from each
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`source.
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`36. Time alignment can be used for another source to have each of its shots
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`adjusted to a given reference time. Necessarily, the other sources will have
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`varying firing times relative to this new reference time and the same principles
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`involving data from shots being in-phase and out-of-phase will apply.
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`B.
`Summary of the ‘981 Patent
`37. The ‘981 Patent claims a method and system for conducting marine seismic
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`surveys employing simultaneous shooting. This method and system employ a
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`simultaneous shooting approach that uses time encoding to separate the data
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`resulting from each source. Ultimately, the invention claimed by the ‘981
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`Patent seeks to “[i]dentify[] which seismic source caused the particular events”
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`recorded by the sensors in order to “determine[] subsurface structures.” (Ex.
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`1001 at 3:66-4:3).
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`
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`Declaration of Luc T. Ikelle in Support of Petition for Inter Partes Review of U.S.
`Patent No. 6,906,981
`38. The invention claimed in the ‘981 Patent utilizes multiple seismic energy
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`sources fired with time delays between them. The sources are activated in what
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`the ‘981 Patent calls a “firing sequence.” The ‘981 Patent defines a firing
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`sequence as “[f]iring the first source, waiting the predetermined time delay and
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`firing the second source.” (Ex. 1001 at 5:67-6:2). The ‘981 Patent notes that
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`“[f]or purposes of the invention, seismic signals are recorded a plurality of such
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`firing sequences, typically three or more firing sequences.” (Ex. 1001 at 6:9-
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`12).
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`39. The ‘981 Patent requires that the time delays between each of the firing
`
`sequences have a different value. (Ex. 1001 at 6:9-11). That is, if the first firing
`
`sequence has a time delay of one second between the activation of the first
`
`source and the activation of the second source, no future time delay between
`
`the activations of the sources can be one second. This rule also applies to the
`
`time delays between preceding sources and any additional sources. For
`
`example, in a system with three sources, the time delay between the activation
`
`of the second and third sources cannot be equal to the time delay between the
`
`activation of the first and second sources nor can it be equal to any time delays
`
`used in other firing sequences. (Ex. 1001 at 10:31-36).
`
`40. The preceding aspects of the ‘981 Patent focus on the activation of the sources.
`
`The ‘981 Patent also discusses the separation steps used to allow identification
`
`of the data resulting from each source, prior to processing. Identifying the
`16
`
`
`
`WesternGeco Ex. 1002, pg. 18
`
`
`
`Declaration of Luc T. Ikelle in Support of Petition for Inter Partes Review of U.S.
`Patent No. 6,906,981
`recorded signal components corresponding to the firing of the first source
`
`involves two steps: (1) “determining coherence between the traces within an
`
`individual firing sequence” and (2) “shot to shot coherence determination.”
`
`(Ex. 1001 at 7:56-58, 8:26).
`
`41. Determining trace to trace coherence filters random noise out of the data
`
`because “random noise has substantially no correspondence from trace to
`
`trace.” (Ex. 1001 at 8:10-12). The ‘981 Patent states that determining
`
`coherence from shot to shot respective to one source allows the data resulting
`
`from the other sources to be “substantially removed.” (Ex. 1001 at 8:18-28).
`
`This is because the differing time delays used in each firing sequence cause data
`
`from the other sources to “not have coherence from shot to shot when the
`
`recording time is indexed to [a given source].” (Ex. 1001 at 8:37-40).
`
`42. The only embodiment of the invention claimed in the ‘981 Patent uses CMP
`
`gathers with respect to one particular source to determine shot to shot
`
`coherence. (Ex. 1001 at 8:43-46). As noted in the ‘981 Patent, “[a] CMP
`
`gather with respect to [a given source] comprises a subset of all the traces
`
`(signal recordings) corresponding to each of a plurality of [firings from that
`
`source], in which of the position of [the given source], and the corresponding
`
`sensor for which the trace is presented or processed in the gather have the
`
`same ‘midpoint’ between them.” (Ex. 1001 at 8:46-51). A CMP gather with
`
`respect to one source will show high coherence for data resulting from the
`17
`
`
`
`WesternGeco Ex. 1002, pg. 19
`
`
`
`Declaration of Luc T. Ikelle in Support of Petition for Inter Partes Review of U.S.
`Patent No. 6,906,981
`firing of that source and low coherence for data from the other sources and
`
`noise (coherent or random). (Ex. 1001 at 8:51-56).
`
`43. The preceding sections describe how to identify and separate data originating
`
`from the firing of one particular source. The ‘981 Patent also discusses the use
`
`of “time-aligning” to identify and separate the data originating from the other
`
`sources. (Ex. 1001 at 8:61-63). The time alignment process entails “applying a
`
`time delay to each trace such that the signals from [the second source] all
`
`represent a same time delay from the start of signal recording.” (Ex. 1001 at
`
`8:63-67). Thus, this time delay for the firings of the second source become a
`
`“reference time” and the firings of the first source relative to this reference
`
`time vary between firing sequences. The same principles of determining trace
`
`to trace coherence and shot to shot coherence apply after time alignment,
`
`including the use of CMP gathers. (Ex. 1001 at 9:16-24).
`
`44. The ‘981 Patent has three independent claims, Claims 1 and 31 which are
`
`methods and Claim 23 which is a system. Claim 23 simply discloses a system
`
`for carrying out the method disclosed in Claim 1, which can be seen by
`
`comparing the similar language in the claims.
`
`Claim 1 of ‘981 Patent
`
`Claim 23 of ‘981 Patent
`
`1. A method for seismic surveying,
`comprising:
`
`23. A seismic surveying system,
`comprising:
`
`[a] towing a first seismic energy source
`
`[a] a first seismic energy source;
`
`
`
`18
`
`WesternGeco Ex. 1002, pg. 20
`
`
`
`Declaration of Luc T. Ikelle in Support of Petition for Inter Partes Review of U.S.
`Patent No. 6,906,981
`Claim 1 of ‘981 Patent
`and at least one seismic sensor system;
`
`Claim 23 of ‘981 Patent
`
`[b] a second seismic energy source; a
`vessel adapted to tow the first source, to
`tow the at least one seismic sensor
`array, and to tow the at least one second
`source at a selected distance from the
`first source; and
`
`[c] a controller adapted to actuate the
`first source and the second source in a
`plurality of firing sequences,
`
`[b] towing a second seismic energy
`source at a selected distance from the
`first seismic energy source; and
`
`[c] actuating the first seismic energy
`source and the second seismic energy
`source in a plurality of firing sequences,
`each of the first sequences including
`firing of the first source and the second
`source and recording signals generated
`by the at least one seismic sensor
`system,
`
`[d] a time interval between firing the
`first source and the second source
`varied between successive ones of the
`firing sequences,
`
`[d] the sequences having a time delay
`between firing the first source and the
`second source which varies between
`successive firing sequences,
`
`[e] the times of firing the first and
`second source indexed so as to enable
`separate identification of seismic events
`originating from the first source and
`seismic events originating from the
`second source in detected seismic
`signals.
`
`[e] the times interval of firing the first
`and second source indexed so as to
`enable separate identification of seismic
`events originating from the first source
`and seismic events originating from the
`second source in detected seismic
`signals.
`
`
`45.
`
`
`
`It is clear that elements [a] and [b] of Claim 1 directly correspond to elements
`
`[a] and [b] of Claim 23. Similarly, element [c] of Claim 1 corresponds to
`
`element [c] of Claim 23, element [d] of Claim 1 corresponds to element [d] of
`
`Claim 23, and eleme
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