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First EAGE Workshop on Practical Reservoir Monitoring
- Conference date: 06 Mar 2017 - 09 Mar 2017
- Location: Amsterdam, Netherlands
- ISBN: 978-94-6282-206-1
- Published: 06 March 2017
21 - 40 of 40 results
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Using PRM Data for Reservoir Management - An Interpreter’s View
Authors P. Sabel, T. Kindingstad, T.A. Melby and B. SatyavoluIn this study we will give an example from the user perspective on how PRM data are used in the daily work of the Snorre asset. The Snorre asset is organised teams assigned to particular fault blocks and reservoir management actions are discussed by these teams before actions are decided and taken. Together with downhole measurements, production and other field data, 4D data is regularly used in this context to complement the understanding we have of the reservoir. Time-lapse data acquisition with only a short time lag between the 4D surveys enables detailed correlation of actions taken for reservoir management with the 4D effects observed. Even small-scale actions like water or gas injection into particular stratigraphic zones can now be investigated. The values at stake when producing only one zone sub-optimally can be significant; and we will show an example for one well. Of course the same value potential cannot be assumed to be true for every well and every zone, but taking into account that the Snorre field has 66 active wells, each targeting several stratigraphic layers, this shows that the potential for value generation from PRM data is enormous.
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Permanent Reservoir Monitoring at Jubarte Field - 4D Results and Reservoir Characterization
Authors W.L. Ramos Filho, P. Dariva, C.C. Born, I.B. Zorzanelli, A. Goertz and A. SmithAt the end of 2012, Petrobras installed the first deep-water optical permanent reservoir monitoring (PRM) system over the Jubarte oilfield in the Campos basin offshore Brazil. The PRM pilot project covered approximately 9 sq. km with a fully fiberoptic 4-component (4C) sensor array. All topside optoeletronic equipment was installed on FPSO P-57. The primary objective was to validate the fiberoptic sensing technology to detect subtle impedance changes in the reservoir. This goal was achieved, allowing interpreters to apply an interpretation strategy to improve the understanding of flow patterns and to update the geological scenarios of the area based on very high quality 3D/4D images provided by the permanent system.
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Production-calibrated Interpretation of 4D Seismic Effects at Grane Field
Authors M. Ravasi, S.S. Roy, S. Agostini and M. AyzenbergGrane Permanent Reservoir Monitoring System has been installed in 2014 and five PRM surveys have been acquired till date. High quality 4D seismic is part of standard work process in Grane and ensures better well planning and optimization, production and injection well monitoring, and completion health check. Being able to identify relationships and trends between various types of dynamic data (e.g. 4D seismic and production) allows for better understanding of reservoir behaviour, which then translates into efficient actions with regard to well planning/optimization as well as model update for better predictions. In this work, we have identified a strong correlation between the liquid (cumulative oil plus water) production and a 4D seismic attribute sensitive to gas-oil contact movement for the Grane field, which has also helped to convert 4D responses into thickness changes and quantify the gas movement.
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Quantitative Seismic Reservoir Monitoring by Using a Wave-equation Based AVO Technology
Authors P. Haffinger, P. Doulgeris and A. GisolfThe authors describe a wave-equation based AVO technology with a specific focus on applications for reservoir monitoring. Introducing the wave-equation into the field of seismic reservoir characterisation allows derivation of quantitative reservoir models, including potential time-lapse changes, from band-limited seismic data. This is a consequence of properly modelling and utilising complex wave effects as internal multiple scattering, mode conversions and travel-time changes due to production effects. The scheme inverts for compressibility and shear compliance which are much more sensitive to changes in the reservoir fluids compared to conventional acoustic and shear impedances. While seismic angle/offset gathers in time are input to the method, the resulting reservoir models are directly in the depth domain. This intrinsic time-depth conversion is another benefit of using the wave-equation and simplifies integration of the reservoir model into reservoir modelling and simulation workflows.
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Simultaneous Joint Migration Inversion for Accurate Time-lapse Analysis of Sparse Monitor Surveys
Authors S. Qu and D.J. VerschuurWe propose that Simultaneous Joint Migration and Inversion (SJMI) as an effective time-lapse tool, does not require dense source/receiver sampling and is suitable for inexpensive sparse monitoring surveys, because of both the inversion process inside the imaging/inversion scheme and the extra illumination provided by multiples. Furthermore, with the help of SJMI, we design an interleaved survey by shooting the sparse surveys without exact acquisition repetition, which provides us further extra illumination of the subsurface to handle the geometry sparsity. With one complex synthetic example based on the Marmousi model, we demonstrate that the extra illumination provided by both imaging/inversion with multiples and changing the survey during monitoring can provide us better time-lapse results, if the proper method is applied to the datasets.
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Full Waveform Inversion for Reservoir Monitoring - Pushing the Limits of Subsurface Resolution
Authors M. Maharramov and B.L. BiondiFluid movement in the subsurface and the associated changes in saturation translate into changes of the subsurface elastic parameters. Stress changes, whether due to fluid extraction/injection or deformation such as slips on preexisting faults, affect the elastic parameters as well. Detecting and inverting the imprint of changing subsurface elastic parameters on seismic data lies at the heart of time-lapse seismic imaging for reservoir monitoring. In this work we demonstrate that the recently proposed technique of simultaneous time-lapse full-waveform inversion with a model-difference regularization can be used to extract high-resolution information on magnitude and location of subsurface velocity and stress anomalies, potentially providing valuable input for reservoir monitoring and assessment of geohazards.
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4D Full Waveform Inversion - A North Sea Case Study
Authors H. Hoeber, E. Hicks, M. Houbiers, S. Pannetier-Lescoffit, A. Ratcliffe and V. VinjeUsing highly repeatable permanent reservoir monitoring data from the Grane field in the Norwegian North Sea we show 4D FWI results using data with a seven-month acquisition interval between vintages. 4D FWI results show changes at the reservoir level that correlate with both injecting and producing wells. In addition, we find good agreement comparing the velocity differences from 4D FWI to 4D time-shifts and time-strains from fully processed and imaged seismic reflection data. We discuss the two methods used, potential limitations, and further work. Overall, this case study demonstrates the robustness of the seismic reflection processing as well as the potential of time-lapse FWI as a complementary reservoir monitoring tool.
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InSAR - Pro-active Remote Sensing for Reservoir Management and Monitoring Environmental Safety
Authors M.E. Allan, P.B. Leezenberg and R.F. HanssenInterferometric Synthetic Aperture Radar (InSAR) is a satellite-based technology that measures minute changes of surface elevation through time. These deformation changes, often less than 1 mm/month, may be caused by changes in the subsurface (e.g., imbalance between fluid withdrawal and injection, collapse of underground mines), or changes at the ground surface (e.g., surface blisters caused by shallow injection of steam or out-of-zone fluid movement, slope failures). Radar waves from successive passes of polar-orbiting satellites provide trillions of 3m by 3m pixels worldwide on a daily to monthly frequency. Using cloud computing and interferometry, the pixels over areas of interest can be used to monitor activities within oil and gas reservoirs, and also to give warnings of possible problems developing at the surface. Examples are shown for the Belridge giant oil field (California), Groningen giant gas field (the Netherlands), and the Peace River area (Alberta). In the three cases, surface deformation is used to monitor areal conformance in the reservoirs. Also, having satellite passes every 11 days means that reservoirs can be monitored proactively and the resultant datasets have the potential to replace traditional 4D seismic at a cost that is significantly less.
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How 4D Gravity and Subsidence Monitoring Provide Improved Decision Making at a Lower Cost
Authors M. Lien, R. Agersborg, L.T. Hille, J.E. Lindgård, H. Ruiz and M. VatshelleWhole-field subsidence and gravity monitoring is a well-proven, cost-efficient technology, with many field cases demonstrating both the high accuracies obtained and the value of the data for improved reservoir management. Seafloor subsidence and 4D gravimetric data are acquired with a small cost compared to seismic data. However, workflows for properly taking advantage of the information that lies in these data and their range of applicability are in general less widely known that for more conventional datasets. This abstract introduces first the principles behind offshore subsidence and 4D gravity monitoring. It then describes some field cases from the Norwegian Continental shelf (NCS) in which subsidence and 4D gravity data have been integrated into the field management workflow for production optimization and enhanced recovery. Finally, new developments towards making the technology even more cost efficient and the added value that can be expected as a consequence of these improvements are discussed.
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Four Decades of Gravity Monitoring of the Groningen Gas Field
Authors O. Eiken, M. Glegola, S. Liu and M.A. ZumbergeFirst, basics of modern microgravity monitoring and accuracies of alternative techniques are discussed. The history of gravity monitoring at the Groningen gas field is reviewed, with first survey aquired in 1978 and the most recent in 2015. The 2015-survey was aquired in a 24/7 operation, at a densified grid of 98 stations. Station uncertainties are estimated at 1.2 microGal (standard deviation). Gravity reductions of up to 84 microGal are estimated in the time-span 1978-2015, likely caused by the gas extraction. The most recent gravity survey on Groningen shows the feasibility of achieving 1-2 microGal in land surveys when using multiple relative meters, multiple visits, 24/7 operation, reference stations outside the reservoir and ties to absolute gravity stations.
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A Long-term Seafloor Deformation Monitoring Campaign at Ormen Lange Gas Field
Authors R. de Vries, T. Noble, P. Hatchell, S. Dunn, T. Frafjord and A. van den BeukelSeafloor deformation monitoring is a new technology concept for offshore oil and gas reservoir monitoring. It has the potential to cheaply and continuously monitor long term production induced changes in the reservoir and overburden and the data can also be used to spot any instantaneous events such as overburden instability or fault slip. At Ormen Lange, Norway´s second largest gas field, a small trial network was deployed on the seafloor in 2007, followed by a full-field network in 2010. The network was operational for 5½ years before being retrieved in 2016.
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The Impact of Environmental and Acquisition Variations for PRM 4D Processing - Snorre Case Study
Authors K. McCluskey, S. Buizard, M. McCluskey, R. Zietal and N. MoyleSince going live in 2014, five permanent reservoir monitoring (PRM) surveys have been acquired over the Snorre field at regular intervals. The PRM installation itself is currently the largest in the world consisting of 57 cables containing ~10,000 multi-component (4C) buried receivers and covering an area of around 200km2. The processing effort of the early PRM surveys was dedicated to establishing and optimising a robust, repeatable sequence with the objective of providing fast turnaround, high quality 4D seismic data. For key processing steps such as geophone reorientation and PZ summation the high degree of receiver repeatability allows us to apply operators derived on the base to subsequent monitor datasets. However, variations in environmental and acquisition conditions between surveys are observed and can impact the 4D response (generating so-called 4D noise). The purpose of this abstract is to highlight some of these issues and how they are dealt with in the context of fast delivery Snorre PRM data. The topics summarised are those which have been especially important to the Snorre dataset: source layback, water velocity and shot coverage harmonization.
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Very Sparse OBS Acquisition for 3D/4D Reservoir Imaging with High-order Multiples. Application to Jubarte PRM
Authors D. Lecerf, C. Barros, E. Hodges, A. Valenciano, N. Chemingui, S. Lu, P. Johann and E. ThedyA receiver’s decimation study has been performed, using the PRM Jubarte dataset acquired by Petrobras, for assessing the potential of very sparse seabed acquisitions in conjunction of a high-order multiple imaging techniques. This imaging process make use of the multiple reflections to increase significantly the fold, enabling therefore sparser seabed recording geometry without compromising the 3D or 4D image quality. The presented decimation test consists on taking out receiver included into circular patches within a diameter of 600 m. The number of sensor is then reduced by a factor two. The results demonstrate that it is possible the break some established limit in term of seabed sensor sparseness without compromising the resolution of 3D/4D imaging.
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Dip-angle Image Filtering for 4D Processing of Towed-streamer and OBN Datasets
Authors R.R. Haacke, L. Casasanta, S. Hou and J.R. HendersonOcean-bottom data are often acquired in the development and production stages of an oilfield’s lifecycle to guide well placement and water injection strategy. Although well suited to time-lapse monitoring, this type of ocean-bottom survey will miss the first time-step in which a field is explored, appraised, and undergoes initial fluid production. To capture this time step it is necessary to 4D co-process ocean-bottom data with the exploration dataset, usually surface towed streamer. Our example from the North Sea benefits from flexible trace pairing to produce high-fold subsets of the input data that generate more similar images than would otherwise be available. However, residual multiple generates significant 4D noise, as does un-cancelled migration operator from the very different, irregular, survey geometries. Migration to: (1) common-offset, (2) scattering-angle, and (3) dip-angle output domains provide opportunity to explore similarity-filtering strategies with the data. The scattering- and dip-angle gathers respond well to similarity filtering, but results show greater spatial resolution, signal continuity, and coherence when dip-angle gathers are used. Dip-angle is an intuitive domain in which to locate and attenuate un-cancelled migration operator in 4D, which is advantageous as migration noise is a major source of 4D noise in these data.
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DAS VSP in Deepwater GoM for Reservoir Monitoring - Lessons Learned
Authors M. Tatanova, D. Chalenski, A. Mateeva, P. Zwartjes, Z. Yang and J. LopezSeismic monitoring of Deepwater fields with ocean bottom nodes (OBN) has proven to deliver very high quality 4D data that impact field-development decisions and ensure the safety and efficiency of operations. However, the frequency of 4D OBN surveys is limited by the cost of acquisition, constraining its applicability to well and reservoir management (WRFM). A lower-cost 4D solution is needed for WRFM, such as Distributed Acoustic Sensing Vertical Seismic Profiles (DAS VSP). We proved the concept of reservoir monitoring with DAS 4D VSP in Deepwater GoM by achieving an NRMS of 7% and getting 4D VSP images comparable to those from the 4D OBN seismic in a wide range of depths. In addition to their monitoring value, recorded DAS VSP data have been used to explore the impact of various factors on DAS-VSP images, including fiber type and length, well flow conditions, and different airgun strengths. This paper will focus on lessons learned from the processing and acquisition of the DAS data, and the path forward on how to make the monitoring with DAS VSP even more affordable.
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Improving 4D Seismic Interpretation and Seismic History Matching Using the Well2seis Technique
Authors Z. Yin, M. Ayzenberg and C. MacBethA well2seis technique is proposed to incorporate available reservoir data from both 4D seismic and well production domains through cross-correlation, to prevent biased reservoir interpretation. The subsequent well2seis attribute shows the capacity to enhance dynamic reservoir interpretations by quantitatively integrating 4D seismic responses with their corresponding well behaviours. It reduces the interpretation workload by avoiding the need to work on many individual 4D differences separately. A joint workflow is then proposed to close the loop between the observed data and the predictions from the simulation model using the well2seis results. This workflow sequentially makes use of direct updating (for updating static models) and assisted history matching (for updating dynamic models) procedures. In the assisted history matching stage, the well2seis correlation attribute successfully acts as an alternative history matching attribute to the conventional production or 4D seismic data. The application of the proposed approach to a North Sea field shows that both the seismic and production history matching results are simultaneously improved to a satisfactory degree when minimising the misfit between the observed and simulated well2seis attributes.
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Automated Workflows Using 4D Seismic in History Matching
Authors T. Hance, S. Fowler, M. Riviere, B. Davies, M. Ball, J. Bradley and C. SelwoodTime-lapse seismic is a key surveillance tool, particularly for managing and maximising value from waterflood fields. To enable efficient integration of 4D results into the simulation model history match a 4D Assisted History Matching (4DAHM) tool has been developed. 4DAHM enables the calibration of dynamic models to 4D changes caused by water, gas and pressure changes. This allows simultaneous matching of reservoir simulation models to seismic and well data. For fields where it has been applied 4DAHM has delivered better-constrained models, better predictions for depletion planning and a time saving of 50% over previous approaches. This paper presents the 4DAHM workflow along with two case studies. 4D Assisted History Matching delivers a flexible and efficient means of incorporating 4D seismic data into an assisted history matching or 4D integration workflow - but as with any tool, informed use and good cross-discipline communication are key in maximizing value.
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Accommodating the V's. Rapid Quantitative Analysis in a Multidisciplinary 4D Environment
Authors B.J. Lynch, G. Brew and J. WheelwightRapid, easy access to a asset's multidisciplinary data coupled with time-lapse seismic should not be underestimated as a success factor in the 4D workflow. The frequent data acquisition, combined with economic pressures for return on investment, put considerable delivery pressures on asset teams. Once integrated, the availability of tools to quantitatively compare anomalies identified in the seismic data with the same areas in the dynamic flow models allow the provision of assisted history matching (AHM) workflows. Such robust and repeatable processes allow the reservoir model to be iteratively improved. Reducing uncertainty and leading to better reservoir management.
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4D Seismic History Matching of the Norne Field Model Using Ensemble-based Methods with Distance Parameterization
Authors Y. Zhang, O. Leeuwenburgh, S. Carpentier and P. SteeghsQuantitative use of 4D seismic data for history matching is still challenging. This is partly because of the high dimensionality and the large uncertainty involved in the seismic data. To circumvent these difficulties there have been some methods proposed with a focus on reparameterization of seismic attributes and reformulation of seismic objective functions so that the integration of 4D seismic data is more robust and efficient. A distance parameterization of seismic anomalies due to saturation effects was previously proposed to history match reservoir models in combination with the ensemble Kalman filter (EnKF). Because the parameterization reduces both nonlinearity and the effective number of data, an improved functioning of the EnKF can be achieved. In this paper, we further improve the distance parameterization by adopting a more robust measure of the distance between observed and simulated fronts. Numerical experiments with Norne field model are presented in which improved functioning of the proposed method is demonstrated.
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Large-scale Numerical Simulation of Reservoir Monitoring - SEAM Time Lapse
Authors D. Smit, S. Oppert, J. Stefani, V. Artus, J. Herwanger, P. Popov, A. Bottrill, L. Tan, W. Hu, J. Liu, W. Abriel, R. Detomo, W. Barkhouse and M.L. Oristaglioal oil fields. The reservoir modelling incorporated coupled effects of fluid flow and deformation during a simulated production scenario with 11 production wells and 6 water-injection wells penetrating the reservoir’s three compartments. Field-scale seismic, gravity and electromagnetic surveys were simulated before and after 2 years of production. This six-month project was designed as a pilot for a new multi-year collaborative research effort called SEAM Life of Field which is starting in 2017.
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