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Abstract Amplitudes of Rayleigh waves are known to decrease exponentially away from the surface. If elastic properties of the solid are stratified on a scale much smaller than the wavelength, the Rayleigh-wave amplitude at a given depth should also be affected by the formation properties at that depth: the softer the medium, the larger the amplitude. An increasingly widespread deployment of fiber-optic cables in wells makes it possible to record this depth variation of Rayleigh-wave strain amplitudes and their variations over time (due to changes of formation properties) using distributed acoustic sensing (DAS). To investigate this opportunity, we have explored temporal variations of downhole DAS amplitudes of ocean-generated Rayleigh waves during injection of CO2 into a water-saturated thin porous layer. Analysis of these data clearly shows changes of these amplitudes related to the CO2 injection. To understand these amplitude variations, we perform a theoretical analysis and numerical simulations, which explain our field observations. In particular, analysis of downhole DAS data and theoretical modeling show that Rayleigh-wave amplitudes measured with vertical fiber-optic cables can be used to detect thin layers in the subsurface. Furthermore, time-lapse analysis of these amplitudes indicates temporal changes of stiffness of these layers, such as changes in saturation or pressure of the fluid in a porous layer in the vicinity of the borehole. In particular, Rayleigh-wave amplitudes are sensitive to the presence in the vicinity of the wellbore of a CO2 plume created as a result of a small injection into a thin porous reservoir layer. Our analysis also shows that the effect of a thin layer on Rayleigh-wave amplitudes strongly depends on frequency so that at different frequencies the amplitude is affected by different combinations of elastic properties. This opens an opportunity to use amplitude variations with depth at different frequencies to separately estimate changes in bulk and shear moduli.
- Oceania > Australia (0.46)
- North America > United States (0.46)
- Geology > Geological Subdiscipline > Geomechanics (0.89)
- Geology > Structural Geology > Tectonics > Plate Tectonics > Earthquake (0.30)
- Reservoir Description and Dynamics > Storage Reservoir Engineering > CO2 capture and sequestration (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring > Production logging (1.00)
We apply a sequential inversion scheme combining elastic FWI and Bayesian rock physics inversion to a VSP dataset acquired with accelerometers and collocated DAS fiber at the Carbon Management Canada’s Newell County Facility. The goal is to build a baseline model of porosity and lithology parameters to support later monitoring of CO2 storage. The key strategies include an effective source approach to cope with near-surface complications, a modeling strategy to simulate DAS data directly comparable to the field data, and a Gaussian mixture approach to capture the bimodality of rock properties. We perform FWI tests on the accelerometer, DAS, and combined accelerometer-DAS data. While the results can accurately reproduce either type of data, the elastic models from the accelerator data outperform the other two in matching well logs and identifying the target reservoir. We attribute this result to the insignificant advantage of DAS data, in this case, over accelerometer data, which also suffers from single-component measurements and lower signal-to-noise ratios. The porosity and lithology models predicted from the accelerometer elastic models are reasonably accurate at the well location and are geologically meaningful in spatial distribution.
- Geology > Rock Type (1.00)
- Geology > Geological Subdiscipline > Geomechanics (0.74)
- Reservoir Description and Dynamics > Storage Reservoir Engineering > CO2 capture and sequestration (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring > Production logging (1.00)
- Health, Safety, Environment & Sustainability > Environment > Climate change (1.00)
Field assessment of elastic full waveform inversion of combined accelerometer and distributed acoustic sensing data in a vertical seismic profile configuration
Eaid, Matthew V. (University of Calgary, Chevron Technical Center) | Keating, Scott D. (University of Calgary) | Innanen, Kristopher A. (University of Calgary) | Macquet, Marie (University of Calgary) | Lawton, Don (University of Calgary)
Seismic data are a significant facilitator for monitoring in carbon capture and sequestration projects, providing high resolution images of fluid migration, using for example full waveform inversion (FWI). Distributed acoustic sensing (DAS), a relatively novel technology for wavefield sampling, is well suited for this type of monitoring. Employing non-invasive optical fibers, DAS allows for dense spatial sampling along the entire length of the well bore, without disrupting operations. Permanently installed in the wellbore, typically behind casing, DAS offers highly repeatable and dense sampling of the transmitted wave modes crucial to seismic monitoring of injected carbon dioxide. However, DAS data consists of measurements of strain along the tangent of the fiber, and therefore does not port directly to conventional FWI algorithms. We describe how DAS data in its native strain (or strain-rate) form can be incorporated into standard FWI algorithms, through changing the definition of a receiver sampling operator that uses geometrical information about the fiber to supply tangential strain measurements to the FWI residual. The theoretical developments are applied to invert field VSP acquired with both DAS fiber and accelerometers at a carbon dioxide sequestration site in Newell Country, Alberta. Our method incorporates DAS data and accelerometer data in one objective function, and allows us to tune the relative importance we wish to place on each dataset. This method should also transfer to non-collocated sensors, for example surface deployed geophones and borehole fiber. The inverted models contain features expected from the geology of the field site, and data modeled in the inverted models compares favorably with field data for both sensor types. The models derive from data acquired prior to CO2 injection, representing baseline models for future timelapse studies planned at the field research station.
- North America > United States (0.67)
- North America > Canada > Alberta (0.48)
- Reservoir Description and Dynamics > Storage Reservoir Engineering > CO2 capture and sequestration (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Near-well and vertical seismic profiles (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring > Production logging (1.00)
Summary The loss of well integrity in oil and gas and CO2 injection wells provokes leaks that potentially pollute underground water reservoirs and the surrounding environment. The present publication reviews the existing literature investigating the loss of well integrity due to damage development in the cement sheath, focusing on qualitative and mainly quantitative information regarding cracks, effective permeability, and leak flows. Methods applied for leak detection on-site are reviewed, and the difficulties of these methods in providing quantitative results are highlighted. The outputs of laboratory experiments and computer simulations, considered essential to complement on-site measurements, are also reported. The review of the existing literature shows that for most of the damaged cement sheaths the observed crack widths range between 1 and 500 µm, the permeability ranges from 10 to 10 m, and the leak rates range between 10 and 10 000 mL/min for gas leaks and between 1 and 1000 mL/min for oil leaks.
- South America (1.00)
- North America > United States > Texas (1.00)
- Asia > Middle East (1.00)
- (3 more...)
- Research Report > New Finding (0.67)
- Overview (0.67)
- North America > United States > West Virginia > Appalachian Basin > Marcellus Shale Formation (0.99)
- North America > United States > Virginia > Appalachian Basin > Marcellus Shale Formation (0.99)
- North America > United States > Pennsylvania > Appalachian Basin > Marcellus Shale Formation (0.99)
- (11 more...)
I had the privilege to lead two mining, and smart cities. It also has finances, membership, challenges, and task forces initiated by then-President afforded me an opportunity to learn opportunities, all of which are important Rick Miller, which resulted in the about many other topics that are influencing topics to know to lead an organization.
- South America (1.00)
- Europe (1.00)
- Asia > China (0.93)
- (3 more...)
- Research Report (1.00)
- Instructional Material > Course Syllabus & Notes (1.00)
- Financial News (1.00)
- (3 more...)
- Geology > Geological Subdiscipline (1.00)
- Geology > Rock Type (0.92)
- Geology > Structural Geology > Tectonics > Plate Tectonics > Earthquake (0.46)
- Materials > Metals & Mining (1.00)
- Law (1.00)
- Government > Regional Government > North America Government > United States Government (1.00)
- (11 more...)
- South America > Brazil > Brazil > South Atlantic Ocean > Santos Basin (0.99)
- Oceania > Australia > Western Australia > North West Shelf > Browse Basin > Caswell Basin > Ichthys Field (0.99)
- North America > United States > Louisiana > China Field (0.89)
- (2 more...)
- Well Completion > Hydraulic Fracturing (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs (1.00)
- Reservoir Description and Dynamics > Storage Reservoir Engineering > CO2 capture and sequestration (1.00)
- (17 more...)
Static Gradient Survey Reveals Temperature Anomaly in the CaMI CO2 Injection Well
Behmanesh, Hamid (Carbon Management Canada) | Cooper, Joanna (Carbon Management Canada, University of Calgary) | Macquet, Marie (Carbon Management Canada) | Kolkman-Quinn, Brendan (Carbon Management Canada) | Lawton, Donald (Carbon Management Canada, University of Calgary) | Osadetz, Kirk (Carbon Management Canada) | Maidment, Greg (Carbon Management Canada)
Abstract In view of the complex wellbore dynamics associated with liquid/vapor CO2 in the Containment and Monitoring Institute (CaMI) of Carbon Management Canada (CMC) CO2 injection wellbore, a Static Gradient Survey was conducted with the focus on the verification of in-tubing pressures and temperatures at various depths in the wellbore. Specifically, the knowledge sought was to learn about the temperature profile in the regions above and below the gas-liquid interface as well as the temperature profile below the Distributed Temperature Sensing (DTS) fiber termination point in the well, where there is no temperature measurement. For the static gradient survey, four surveys (passes) were conducted over a span of 6 hours, using tandem pressure/temperature recorders. For the first and second passes, loweringand raisingthe wireline string in and out of the wellat a steady rate was undertaken. The third pass involved stopping the gauges at specified depths for approximately 10 minutes prior to extracting them out of the wellbore. Recognizing that the responses of the gauges to temperature were much slower than to pressure, the duration of the stops variedat different depths, depending on the location of interest. The final pass took place some 6 hours after the initial run. The location of the liquid level in the well was identified, not only by the change in pressure gradients but also by a change in temperature gradients. At the gas-liquid interface, the liquid was boiling and caused localized cooling around the interface. This cooling event was registered in the DTS data where the temperature departed from the baseline temperature gradient. Another cooling event was observed near the base of the wellbore where the recorded temperature profile cooled before it again approached the normal thermal gradient. We interpreted the cause of this cooling event to be that some of the injected CO2 has migrated up-section into the shallower formation. The corresponding decrease of pressure caused a phase change and evaporationof CO2 which resulted in a reduction in the CO2 temperature. The temperature anomaly at the base of the injection well is consistent with the geophysical monitoring results from vertical seismic profiles (VSP) and the borehole electrical resistivity tomography (ERT) surveys. Understanding of the thermal processes related to Geologic Carbon Storage(GCS) is crucial for a successful deployment of projects. Our observations of temperature anomalies within the reservoir will contribute to the feasibility of employing temperature signals as a monitoring tool for the subsurface migration of the CO2 plume.
- Geology > Geological Subdiscipline (0.68)
- Geology > Rock Type > Sedimentary Rock (0.46)
- Well Completion > Completion Monitoring Systems/Intelligent Wells > Downhole sensors & control equipment (1.00)
- Reservoir Description and Dynamics > Storage Reservoir Engineering > CO2 capture and sequestration (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization (1.00)
- (3 more...)
Design for preventing or minimizing the effects of accidents is termed accidental limit states (ALS) design and is characterized by preventing/minimizing loss of life, environmental damage, and loss of the structure. Collision, grounding, dropped objects, explosion, and fire are traditional accident categories.
- South America > Brazil (1.00)
- Oceania > Australia (1.00)
- North America > Canada (1.00)
- (11 more...)
- Summary/Review (1.00)
- Research Report > New Finding (1.00)
- Research Report > Experimental Study (1.00)
- (3 more...)
- Geology > Mineral (1.00)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Sedimentary Geology > Depositional Environment (0.67)
- Geology > Structural Geology > Tectonics > Plate Tectonics (0.67)
- Transportation > Marine (1.00)
- Transportation > Infrastructure & Services (1.00)
- Transportation > Ground (1.00)
- (36 more...)
- South America > Brazil > Campos Basin (0.99)
- North America > United States > Gulf of Mexico > Central GOM > East Gulf Coast Tertiary Basin > Viosca Knoll > Block 786 > Petronius Field (0.99)
- North America > United States > Gulf of Mexico > Central GOM > East Gulf Coast Tertiary Basin > Mississippi Canyon > Block 392 > Appomattox Field (0.99)
- (58 more...)
_ Fiber optics represents one of the biggest technological success stories in the recent history of the oil and gas industry. A single fiber-optic cable installed outside the casing, inside the tubing, can deliver a wealth of data over a well’s life cycle. It can sense minute shifts in acoustics, temperature, and has recently been developed to detect changes in near-wellbore strain—all prized clues as to what is helping or hurting productivity. But less than a decade ago, the ultrathin glass cables were considered exotic, and only a handful of first adopters dared to deploy them downhole. The sensing technology has, of course, gone on to become a mainstay of subsurface diagnostic programs for operators working across the planet. Now, with their skills sharpened in the upstream industry, many fiber-optics developers are gearing up for what appears to be a coming boom in carbon capture and storage (CCS) capacity. Among them is UK-based Silixa. Founded in 2007, Silixa’s innovations have improved on the spatial resolution of fiber measurements and enabled real-time monitoring of fracture growth and production. Last year, the company installed the world’s first subsea distributed acoustic sensing (DAS) system for BP to enable 4D seismic acquisition in the Gulf of Mexico. Glynn Williams, CEO of Silixa, shares in this Q&A how all this experience points to fiber having a major role to play in the rise of the CCS sector—especially when it comes to safety and regulatory matters. His background features more than 30 years spent in the upstream industry’s data acquisition arena. Williams also holds a degree in mining engineering from the University of Wales and is a member of SPE. Where do you see the carbon sequestration sector headed—is an inflection point coming? This now consumes a lot of my time. We see CCS as a huge opportunity because we’ve been engaged with the sector for a long period of time. For the type of solutions that we deliver, we can extract perhaps $1 of value for each ton per year of CO2 that is stored. When you look at the projections by the IEA, which suggest we may be storing over 7.5 gigatons of CO2 by 2050, that relates to $7.6 billion of value. That’s if we were to be successful in securing all of that—there will be other players alongside us. But to this point, we’ve provided services to 17 CCS sites going back as early as 2012. So, we’ve got a track record with our environmental business unit that serves CCS, and we’re seeing in the current period a twofold increase in pipeline opportunities. We feel that particular business unit will account for 40% of our overall pipeline in 2023.
- North America > United States (0.34)
- North America > Mexico (0.34)
- Europe > United Kingdom > Wales (0.25)
- Reservoir Description and Dynamics > Storage Reservoir Engineering > CO2 capture and sequestration (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring > Production logging (1.00)
- (2 more...)
Fiber optics represents one of the biggest technological success stories in the recent history of the oil and gas industry. A single fiber-optic cable installed outside the casing, inside the tubing, can deliver a wealth of data over a well's life cycle. It can sense minute shifts in acoustics, temperature, and has recently been developed to detect changes in near-wellbore strain--all prized clues as to what is helping or hurting productivity. But less than a decade ago, the ultrathin glass cables were considered exotic, and only a handful of first adopters dared to deploy them downhole. The sensing technology has, of course, gone on to become a mainstay of subsurface diagnostic programs for operators working across the planet.
- Well Completion > Hydraulic Fracturing (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring > Production logging (1.00)
- (3 more...)
Monitoring subsurface changes by tracking direct-wave amplitudes and traveltimes in continuous distributed acoustic sensor VSP data
Pevzner, Roman (Curtin University) | Glubokovskikh, Stanislav (Curtin University, Lawrence Berkeley National Laboratory) | Isaenkov, Roman (Curtin University) | Shashkin, Pavel (Curtin University) | Tertyshnikov, Konstantin (Curtin University) | Yavuz, Sinem (Curtin University) | Gurevich, Boris (Curtin University) | Correa, Julia (Lawrence Berkeley National Laboratory) | Wood, Todd (Lawrence Berkeley National Laboratory) | Freifeld, Barry (Class VI Solutions, Inc.)
ABSTRACT Instrumenting wells with distributed acoustic sensors (DASs) and illuminating them with passive or active seismic sources allows precise tracking of temporal variations of direct-wave traveltimes and amplitudes, which can be used to monitor variations in formation stiffness and density. This approach has been tested by tracking direct-wave amplitudes and traveltimes as part of a carbon capture and storage project where a 15 kt supercritical CO2 injection has been monitored with continuous offset vertical seismic profiling using nine permanently mounted surface orbital vibrators acting as seismic sources and several wells instrumented with DAS cables cemented behind the casing. The results indicate a significant (from 15% to 30%) increase of strain amplitudes within the CO2 injection interval, and traveltime shifts of 0.3–0.4 ms below this interval, consistent with full-wave 1.5D numerical simulations and theoretical predictions. The results give independent estimates of the CO2 plume thickness and the associated P-wave velocity reduction.
- Reservoir Description and Dynamics > Storage Reservoir Engineering > CO2 capture and sequestration (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Near-well and vertical seismic profiles (1.00)
- (2 more...)