Jakob B. U. Haldorsen

MagiQ Technologies (United States)

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Douglas E. Miller

University of Victoria

R. Coates

University of Birmingham

Nicholas Brooks

READ Global

M. Milenkovic

READ Global

L. Jahren

READ Global

William H. Borland

Schlumberger (British Virgin Islands)

Mary L. Krasovec

New England Research (United States)

Stewart T. Taylor

Schlumberger (Norway)

T. Hilton

READ Global

W. Scott Leaney

Schlumberger (United States)

Cooperative Institutions

Schlumberger (British Virgin Islands)

European Organization for Nuclear Research

University of Oslo

Massachusetts Institute of Technology

Istituto Nazionale di Fisica Nucleare, Sezione di Genova

Laboratoire d’Annecy de Physique des Particules

Schlumberger (United States)

University of Genoa

University College London

University of Bergen

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Leveraging multiple source locations and the total wavefield to create a more robust salt proximity survey: Gulf of Mexico example, Tahiti Field

T. A. Bollmann Bryan Harvey David Dushman George Rhoads Robert D. Shank

In the Gulf of Mexico, salt proximity surveys are typically acquired with only a single offset energy source location and a short array of receivers at varying measurement levels. This array is placed in a wellbore with close proximity to a nearby salt body. The result is a single profile of salt exit points that may not fully describe the localized salt structure we are attempting to define. For this project, a salt proximity survey using 13 different source locations was designed and implemented to create a more robust 3D result when compared to the more limited coverage of traditional survey configurations. The initial results and baseline processing solution involved industry standard proven techniques where traveltime variances between a modeled output and measured refracted P wave direct arrival time through the entire velocity field are analyzed. To fully exploit the acquired dataset, this more traditional methodology using direct arrival P wave traveltimes was corroborated by a second set of exit points derived from an alternate processing method using mode converted S wave arrivals from the base of salt. The final outcome was two distinct, and comparable salt exit point results culminating in a high confidence, localized, 3D salt surface that reduced the salt face uncertainty in the area from ±1000 ft to ±100–200 ft to help identify updip attic potential and new drilling opportunities. Presentation Date: Wednesday, September 18, 2019 Session Start Time: 1:50 PM Presentation Time: 4:45 PM Location: 217C Presentation Type: Oral

Seismic survey

Field survey

Survey research

10.1190/segam2019-3216302.1

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Fault delineation using earthquake energy as a source for pre-stack depth imaging

Jakob B. U. Haldorsen Stewart T. Taylor Douglas E. Miller

Summary The San Andreas Fault Observatory at Depth (SAFOD) is a deep borehole observatory constructed to investigate the source of recurring earthquakes at a specific location on the San Andreas Fault. Numerous geophysical datasets were acquired at the SAFOD site to characterize the subsurface environment. Among these, we collected three independent seismic datasets to characterize the local geologic structure. These datasets include VSP, drill-bit noise, and earthquake recordings. Initially, interferometric deconvolution was applied to the drill-bit noise using Schlumberger patented methods to determine the reference signal from rig-based receivers. Next, it was applied in a modified processing flow to determine the reference signal from downhole receivers. Finally, as a result of the application of the technique to earthquake data, we obtained high resolution imaging of the San Andreas Fault at depths exceeding 2.5 km. In conjunction with the other seismic datasets collected at the site, we interpret the complex system of faults and fractures to constitute a flower structure which is partially exposed at Middle Mountain northeast of the SAFOD site.

10.1190/segam2014-0013.1

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Array-conditioned deconvolution of multiple-component teleseismic recordings

AGU Fall Meeting Abstracts (2010)

C. Chen Douglas E. Miller Hugues Djikpéssé Jakob B. U. Haldorsen S. Rondenay

SUMMARY We investigate the applicability of an array-conditioned deconvolution technique, developed for analysing borehole seismic exploration data, to teleseismic receiver functions and data pre-processing steps for scattered wavefield imaging. This multichannel deconvolution technique constructs an approximate inverse filter to the estimated source signature by solving an overdetermined set of deconvolution equations, using an array of receivers detecting a common source. We find that this technique improves the efficiency and automation of receiver function calculation and data pre-processing workflow. We apply this technique to synthetic experiments and to teleseismic data recorded in a dense array in northern Canada. Our results show that this optimal deconvolution automatically determines and subsequently attenuates the noise from data, enhancing P-to-S converted phases in seismograms with various noise levels. In this context, the array-conditioned deconvolution presents a new, effective and automatic means for processing large amounts of array data, as it does not require any ad-hoc regularization; the regularization is achieved naturally by using the noise present in the array itself.

Array Processing

Regularization

Data Processing

Overdetermined system

Source

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Azimuthal Sonic Imaging

Jakob B. U. Haldorsen William H. Borland Hamad Ahmed Bu Al Rougha A. H. Sultan R. O’Reilly Meehan

I017 Z-99 Azimuthal Sonic Imaging Abstract We have developed a method for generating 3D images from sonic full-waveform data. The data were acquired using the Schlumberger Dipole Sonic Imager (DSI�) tool consisting of four sets of hydrophone receivers arranged around the perimeter of the tool. Each of the four receiver banks consists of eight hydrophones placed along the borehole at ½ ft intervals. After applying adaptive noise cancellation filters and wavefield migration we obtain one image each centered on the corresponding set of azimuthal receivers. A 3D image of the formation is formed by applying spatial shifts dependent on the

Hydrophone

Optoacoustic imaging

10.3997/2214-4609-pdb.1.i017

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Extended High-Frequency Processing of Vibrator VSP Data

Jakob B. U. Haldorsen William H. Borland Huibert B. Heijna

P296 EXTENDED HIGH-FREQUENCY PROCESSING OF VIBRATOR VSP DATA Abstract A seismic vibrator is a nonlinear system and will as a rule generate energy at higher multiples of this frequency in addition to the signal at the intended frequency. We demonstrate that these normally notaccounted-for frequency components can be recovered as signal for vertical seismic profile (VSP) imaging provided the total raw waveforms are used in the deconvolution process. Dukhan Field The Dukhan field located on the west side of Qatar (Figure 1) was discovered in 1939 and was put on production in December 1949. There are currently three producing reservoirs—Arab

Seismic vibrator

Vibrator (electronic)

SIGNAL (programming language)

10.3997/2214-4609-pdb.3.p296

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Comparison of Full Waveform SeismicMWD and Conventional VSP Data from the South Caspian

Jakob B. U. Haldorsen Mary L. Krasovec Sue Raikes T. Harrold David N. Day

B026 Comparison of Full Waveform SeismicMWD and conventional VSP data from the South Caspian 1 J.B.U. Haldorsen 1 M. Krasovec 2 S. Raikes 3 T. Harrold 3 and D.N. Day 3 J.D. Clippard 4 1 Schlumberger-Doll Research Old Quarry Road Ridgefield CT06877-4108 USA 2 Earth Resources Laboratory Massachusetts Institute of Technology 42 Carleton St. Cambridge MA 02142 3 BP Chertsey Road Sunbury on Thames Middlesex TW16 7LN UK 4 Shell E&P Technology Appl. & Research Volmerlaan 8 Postbus 60 2280AB Rijswijk The Netherlands Abstract We demonstrate that full waveform data acquired while drilling using the new Schlumberger Seismic Measurement While

10.3997/2214-4609-pdb.5.b026

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Ray-based Focused Vector Migration for Microseismic Applications

Jakob B. U. Haldorsen

Summary Using simple-minded synthetic data, I demonstrate that "fat-ray" imaging of three-component borehole-seismic data allows for finding an accurate estimates of the location of a microseismic event. The technique is effectively testing whether the recorded three-component data are consistent with the hypothesis that they are generated at a specific point in 3D space, and it appears to effectively resolve ambiguities associated with overlapping microseismic events, as well as angular ambiguities normally associated with spatial aliasing for a sparse array of sensors. As the approach gives high-quality estimates of the location of a microseismic event, as well as good estimates of the seismic signatures generated, the method allows using the propagating energy to image near-by formation structures. It is suggested that large aperture DAS arrays are supplemented by sparse arrays of three-component sensors, in order to resolve directional insensitivities or ambiguities of a DAS sensor.

Microseism

Aliasing

Component (thermodynamics)

10.3997/2214-4609.2021613006

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High-Resolution Processing of VSP Data

Jakob B. U. Haldorsen M. Milenkovic

Summary It is argued that VSP data have better resolution than surface-seismic data because the shorter propagation distance means less absorption of the higher frequencies. However, in most applications, splicing VSP data into surface-seismic images, one is often content with using the VSP image to identify possible artifacts from multiple reflections, and otherwise show the same structures. We demonstrate how properly formulated deconvolution operators do improve the resolution in the data when applied to a rig-source, walk-away, and vertical-incidence VSP data.

Data Processing

Vertical seismic profile

10.3997/2214-4609.2019x604041

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Full-Waveform While-Drilling Seismics, a Case Study from the Grane Field, the North Sea

Jakob B. U. Haldorsen R. Coates S. A. Petersen A. Hawthorn Mark Van Schaack

P231 FULL-WAVEFORM WHILE-DRILLING SEISMICS A CASE STUDY FROM THE GRANE FIELD THE NORTH SEA Introduction 1 R.T. COATES 1 J. B.U. HALDORSEN 1 S.A. PETERSEN 2 A. HAWTHORN 3 and M. VAN SCHAACK 4 In most exploration and in some development wells the seismic map is the primary guide for well placement. The estimated depth to a seismic target is based on certain assumptions with regard to the anisotropy of the formation. These assumptions are necessary because the surface-seismic data give poorly constrained estimates of the vertical velocities. However borehole-seismic travel times give a direct calibration of the vertical velocity

Vertical seismic profile

North sea

Economic geology

10.3997/2214-4609-pdb.3.p231

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Extending the seismic bandwidth — A simultaneous uncorrelated VSP and surface seismic field test study

Peter I. Pecholcs Riyadh Al‐Saad Huibert B. Heijna Jakob B. U. Haldorsen R. Coates

A controlled simultaneous VSP and surface seismic field test was conducted to evaluate the evolution of the vibroseis chirp wavelet. We verify that the partitioning of seismic energy is independent of sweep rate for different sweep designs. We demonstrate under what conditions the seismic bandwidth can be extended using the semblance‐weighted deterministic deconvolution process in the uncorrelated domain for zero‐offset VSP, walk‐away VSP, and simultaneous borehole and surface seismic data. The deterministic deconvolution process requires knowledge of the chirp wavelet in order to transfer the harmonic energy from the seismic noise domain into the seismic signal domain. Its performance depends on knowledge of the chirp signature and ambient noise. As expected, the ambient noise conditions in the well were extremely low as compared to the higher noise levels recorded in the surface seismic data. Under low ambient noise conditions, the semblance‐weighted deconvolution can extend the recoverable bandwidth beyond the predefined pilot bandwidth for both the VSP and surface seismic data independently. The high level of surface ambient noise conditions in our field test limited the effectiveness of the VSP operators to extend the recoverable bandwidth of the surface seismic data.

Chirp

Vertical seismic profile

Seismic vibrator

Seismic energy

10.1190/1.3054849

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