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Abstract In some basins, large scale development of unconventional stacked-target plays requires early election of well targeting and spacing. Changes to the initial well construction framework can take years to implement due to lead times for land, permitting, and corporate planning. Over time, as operators wish to fine tune their development plans, completion design flexibility represents a powerful force for optimization. Hydraulic fracturing treatment plans may be adjusted and customized close to the time of investment. With a practical approach that takes advantage of physics-based modeling and data analysis, we demonstrate how to create a high-confidence, integrated well spacing and completion design strategy for both frontier and mature field development. The Dynamic Stimulated Reservoir Volume (DSRV) workflow forms the backbone of the physics-based approach, constraining simulations against treatment, flow-back, production, and pressure-buildup (PBU) data. Depending on the amount of input data available and mechanisms investigated, one can invoke various levels of rigor in coupling geomechanics and fluid flow – ranging from proxies to full iterative coupling. To answer spacing and completions questions in the Denver Basin, also known as the Denver-Julesburg (DJ) Basin, we extend this modeling workflow to multi-well, multi-target, and multi-variate space. With proper calibration, we are able generate production performance predictions across the field for a range of subsurface, well spacing, and completion scenarios. Results allow us to co-optimize well spacing and completion size for this multi-layer column. Insights about the impacts of geology and reservoir conditions highlight the potential for design customization across the play. Results are further validated against actual data using an elegant multi-well surveillance technique that better illuminates design space. Several elements of subsurface characterization potentially impact the interactions among design variables. In particular, reservoir fluid property variations create important effects during injection and production. Also, both data analysis and modeling support a key relationship involving well spacing and the efficient creation of stimulated reservoir volumes. This relationship provides a lever that can be utilized to improve value based on corporate needs and commodity price. We introduce these observations to be further tested in the field and models.
Artificial Intelligence, asset and portfolio management, calibration, correlation, Denver Basin, downhole intervention, equation of state, hydraulic fracturing, injection, interpretation, intervención de pozos petroleros, Modeling & Simulation, Niobrara, perforation cluster, permeability, Petroleum Engineer, prediction, production enhancement, relative permeability, Reservoir Characterization, reservoir simulation, Scenario, stimulation fluid, test insight, Upstream Oil & Gas, well density, Well Intervention, well spacing, workflow
Country:
- North America > United States > Wyoming (1.00)
- North America > United States > Colorado (1.00)
Oilfield Places:
- North America > United States > Wyoming > Niobrara Formation (0.99)
- North America > United States > Wyoming > Laramie Basin > Niobrara Formation (0.99)
- North America > United States > Wyoming > DJ (Denver-Julesburg) Basin > Niobrara Formation (0.99)
- (22 more...)
SPE Disciplines:
- Well Completion > Hydraulic Fracturing (1.00)
- Reservoir Description and Dynamics > Reservoir Simulation (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization (1.00)
- (5 more...)
Technology:
Abstract This paper presents construction and validation of a reservoir model for the Niobrara and Codell Formations in Wattenberg Field of the Denver-Julesburg Basin. Characterization of Niobrara-Codell system is challenging because of the geologic complexity resulting from the presence of numerous faults. Because of extensive reservoir stimulation via multi-stage hydraulic fracturing, a dual-porosity model was adopted to represent the various reservoir complexities using data from geology, geophysics, petrophysics, well completion and production. After successful history matching two-and-half years of reservoir performance, the localized presence of high intensity macrofractures and resulting evolution of gas saturation was correlated with the time-lapse seismic and microseismic interpretations. The agreement between the evolved free gas saturation in the fracture system and the seismic anomalies and microseismic events pointed to the viability of the dual-porosity modeling as a tool for forecasting and future reservoir development, such as re-stimulation, infill drilling, and enhanced oil recovery strategies.
Baseline Survey, basin, chalk, Colorado, Colorado School, complex reservoir, Drillstem Testing, drillstem/well testing, dual-porosity model, fracture system, gas production, gas saturation, gas saturation distribution, horizontal well, hydraulic fracturing, Modeling & Simulation, monitor 1, monitor 2, Reservoir Characterization, simulation model, Sonnenberg, study area, Upstream Oil & Gas, US government, Wattenberg field, western side, wishbone section
Country:
- North America > United States > Colorado > Weld County (0.37)
- North America > United States > Colorado > Denver County (0.37)
- North America > United States > Colorado > Larimer County (0.27)
- (3 more...)
Geophysics:
Oilfield Places:
- North America > United States > Wyoming > Niobrara Formation (0.99)
- North America > United States > Wyoming > Laramie Basin > Niobrara Formation (0.99)
- North America > United States > Wyoming > DJ (Denver-Julesburg) Basin > Niobrara Formation (0.99)
- (13 more...)
SPE Disciplines:
- Well Completion > Hydraulic Fracturing (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Geologic modeling (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management (1.00)
Abstract Accelerating the learning curve in the development of the Vaca Muerta utilizing lessons learned in North American unconventional resource plays is the focus of this paper. Reducing completion costs while maintaining high productivity has become a key objective in the current low-price environment. Completion diagnostics have been demonstrated to optimize stimulation and completion parameters that have shaped successful field developments. The paper reviews stimulation diagnostic data from wells completed in the Tuscaloosa Marine Shale, Eagle Ford, Wolfcamp and Niobrara shale formations. Case histories are presented in which proppant and fluid tracers were successfully employed in completion optimization processes. In the examples presented, diagnostic results were used to assess the stimulation of high productivity intervals within a target zone, evaluate various completion methods, and optimize stage and cluster spacing. The diagnostic data were compared with post-frac production rates in an effort to correlate completion changes with well performance. Results presented compare first, engineered perforations versus conventional geometrically spaced perforations to drive up effectiveness in cluster stimulation. Second, new chemistries, such as nanosurfactant, versus conventional chemistries to cut either completion cost or prove their profitability. Third, employing an effective choke management strategy to improve well productivity. Last, as in any stacked pay, determining fracture height growth in order to optimize well density, well spacing, field development and ultimately the recovery of the natural resources. Completion effectiveness is shown to be improved by landing laterals in high productivity target intervals, increasing proppant coverage across the lateral by utilizing the most effective completion methods, optimizing cluster spacing and decreasing the number of stages to reduce completion costs while achieving comparable production rates. Cluster treatment efficiency (CTE), in particular, has become a critical metric when optimizing hydraulic fracturing treatment designs based on current and future well densities. It can be used to rationalize well performance as well as to identify possible candidates for a refrac program. Using completion diagnostics, successful completion techniques were identified that led to production enhancements and cost reductions in prolific plays such as the Tuscaloosa Marine Shale, Eagle Ford, Wolfcamp and Niobrara.
Artificial Intelligence, chemical tracer, communication, Completion Installation and Operations, complex reservoir, concentration, contribution, contribution profile, Eagle Ford, Energy Economics, fracturing fluid, fracturing materials, hydraulic fracturing, knowledge management, lateral, load fluid recovery, machine learning, normalized concentration, oil tracer, operator, production profile, proppant, recovery, rendering, Reservoir Characterization, structural geology, total tracer recovered, tracer, tracer result, tracer test analysis, tuscaloosa marine shale, unconventional resource economics, Upstream Oil & Gas, wellbore
Country:
- North America > United States > Wyoming (1.00)
- North America > United States > Texas (1.00)
- North America > United States > Colorado (1.00)
- (2 more...)
Oilfield Places:
- South America > Argentina > Patagonia > Neuquén > Neuquen Basin > Vaca Muerta Shale Formation (0.99)
- North America > United States > Wyoming > Uinta Basin (0.99)
- North America > United States > Wyoming > Niobrara Formation (0.99)
- (30 more...)
SPE Disciplines:
Origin, Detection, Involvement in Hydraulic Stimulation and Consequences for Field Development of Large-Scale Structural Lineaments in the Marcellus and Duvernay Plays
Stephenson, Ben (Shell Canada Energy) | Galan, Earl (Shell Canada Energy) | Fay, Mathew (Shell Canada Energy) | Savitski, Alexei (Shell International Exploration & Production Inc.) | Bai, Taixu (SEPCO)
Abstract The evidence for large-scale structural features (lineaments/faults) affecting a hydraulic stimulation is much more compelling than for small-scale features (natural fractures). Large-scale features are weaker and have similar dimensions to a typical hydraulic fracture. But is it beneficial to stimulate these features and what are the potential consequences? An analysis of structural features from the Marcellus and Duvernay formations has been undertaken, with static characterization (seismic, image logs and outcrops), dynamic characterization (fracture diagnostics and well performance) and geomechanical modeling; ultimately to understand whether, in the presence of structural features, any field development decisions might get impacted. Maps of structural features supported by seismic attributes are commonly challenged as to what they physically represent. Outcrop analogues demonstrate how strain is distributed in intrinsically layered media, such as shale. Therefore a shale may preferentially fold above a fault. Folding may result in strain partitioning, with bedding-parallel slip (shear) limiting the vertical extent and opening (dilation) of discrete fracture planes. Lineaments in Marcellus folds are either broad zones of axial kink-band deformation associated with higher bedding dips, or planar zones comprising reactivated natural fractures forming an inherited en echelon fabric. Lineaments in the Duvernay are zones of distributed deformation commonly associated with a subtle flexure above faults. A novel interpretation method of microseismic events in time reveals how lineaments are involved during a hydraulic fracture treatment driven by changes in net pressure. Hydraulic half-length is limited when fracs intersect a lineament at a high angle. This was confirmed by geomechanical modelling showing that lineament dilation prevents the opposite branch of the bi-wing frac from propagating. Diagnostics from plays with lineaments oriented close to maximum horizontal stress indicate that the length-scale of hydraulic communication is increased, because tensile reactivation is facilitated. Tracer data have been used to calibrate the conductive length-scale of these features in the sub-surface and also confirm that external fluids may be brought into the well-bore from underlying formations. Whether a lineament helps well productivity depends partly whether it is ‘contained’ or ‘uncontained’ within the over-pressured formation. In the uncontained case, stimulation efficiency and enhanced risk of external fluids needs careful monitoring. In the contained case, stimulation of a lineament may enhance productivity of a stand-alone well, but conversely this same lineament may exacerbate the Parent-Child impact once adjacent wells are drilled. A potential mitigation measure may be to modify the proppant or stimulation design to screen-out these high conductivity (or leak-off) pathways, rather than trying to stimulate them, thereby enhancing near-wellbore complexity. Paradoxically, the best way to handle large-scale structural lineaments may be to stimulate them in order to shut them off.
Artificial Intelligence, complex reservoir, deformation, fracture characterization, hydraulic fracturing, hydraulic stimulation, interpretation, large-scale feature, lineament, marcellus, mechanism, natural fracture, orientation, outcrop, Petroleum Engineer, plane, Reservoir Characterization, reservoir geomechanics, shale gas, Stephenson, structural feature, structural geology, Upstream Oil & Gas, well performance, Wellbore Design, wellbore integrity
Country:
- North America > Canada > Alberta (1.00)
- Asia > Middle East (0.93)
- North America > United States > Pennsylvania (0.68)
- North America > United States > Texas (0.68)
Geophysics:
Oilfield Places:
- North America > United States > Wyoming > Niobrara Formation (0.99)
- North America > United States > Wyoming > DJ (Denver-Julesburg) Basin (0.99)
- North America > United States > West Virginia > Appalachian Basin > Marcellus Shale Formation (0.99)
- (40 more...)
SPE Disciplines:
ABSTRACT: Heterogeneity of an unconventional reservoir is one of the main factors affecting production. Well performance depends on the size and efficiency of the interconnected fracture “plumbing system”, as influenced by multistage hydraulic fracturing. A complex, interconnected natural fracture network can significantly increase the size of stimulated reservoir volume, provide additional surface area contact and enhance permeability. The purpose of this study was to characterize the natural fracture patterns occurring in the unconventional Niobrara reservoir and to determine the drivers that influenced fracture trends and distributions. Highly fractured areas/fracture swarm corridors were identified and integrated into a reservoir model though DFN (Discrete Fracture Network) application for further prediction of reservoir performance using reservoir simulations. The predictive capability of DFN models can aid in improved reservoir performance and hydrocarbon production through optimized well spacing, re-frac stage locations planning for existing wells as well as completion strategies design for new wells.
Artificial Intelligence, complex reservoir, data mining, DFN model, fracture, fracture characterization, fracture distribution, fracture intensity, fracture network, Grechishnikova, horizontal well, hydraulic fracturing, improved development strategy, information, input parameter, intensity, natural fracture network, Niobrara Formation, niobrara play case study, niobrara reservoir, Reservoir Characterization, resolution, subsurface, unconventional reservoir, Upstream Oil & Gas
Geophysics: Geophysics > Seismic Surveying > Passive Seismic Surveying > Microseismic Surveying (0.33)
Oilfield Places:
- North America > United States > Wyoming > Niobrara Formation (0.99)
- North America > United States > Wyoming > Laramie Basin > Niobrara Formation (0.99)
- North America > United States > Wyoming > DJ (Denver-Julesburg) Basin (0.99)
- (9 more...)
SPE Disciplines:
- Well Completion > Hydraulic Fracturing (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Naturally-fractured reservoirs (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Faults and fracture characterization (1.00)
Summary Calcite forms variable proportions of source-rock reservoirs ("shale plays"). Although calcite content can be quantified via petrophysical analyses, XRD, XRF and other techniques, the amount of calcite, by itself, is not enough information to predict the likely importance of these minerals for reservoir and completions quality. Four principle types of calcite can be recognized:Pelagic components, mostly foraminifera and coccoliths, form a large component of the Eagle Ford and Niobrara but other types of pelagic carbonates (e.g., tentaculitids) are common in Paleozoic source-rock plays such as the Marcellus, Carbonate "event beds" (turbidites, storm deposits, etc.) are present in the Avalon, Barnett, Vaca Muerta and other plays, In situ benthic carbonates (bivalves, corals) are present in some plays (e.g., Eagle Ford, Marcellus), and Diagenetic calcites (pore filling cements, fracture fills, replacements, etc.) are present to varying degrees in perhaps most source-rock plays. Detailed core descriptions and petrographic observations are critical for assessing the origin of the calcite. Similar concepts apply to other mineral and organic components of mudstones.
Barnett shale, basin, calcite, carbonate, carbonate event bed, complex reservoir, concretion, Eagle Ford, Energy Economics, event bed, fracture, hydraulic fracture, marcellus, marl, mudstone, oil shale, organism, pelagic carbonate, Reservoir Characterization, shale gas, shale oil, source rock, source-rock play, structural geology, unconventional resource economics, Upstream Oil & Gas
Country:
- North America > United States > Texas (1.00)
- Europe (1.00)
- North America > United States > New Mexico (0.95)
- North America > United States > Colorado (0.68)
Oilfield Places:
- North America > United States > Wyoming > Niobrara Formation (0.99)
- North America > United States > Wyoming > DJ (Denver-Julesburg) Basin (0.99)
- North America > United States > Texas > Permian Basin > Yeso Formation (0.99)
- (65 more...)
SPE Disciplines:
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Shale oil (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Shale gas (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Exploration, development, structural geology (1.00)
Upper Cretaceous Niobrara Chalk in Buck Peak Field, Sand Wash Basin, NW Colorado: Depositional Setting, Lithofacies, and Nanopore Network
Loucks, Robert G. (Bureau of Economic Geology, The University of Texas at Austin) | Rowe, Harry D. (Bureau of Economic Geology, The University of Texas at Austin)
The Upper Cretaceous Niobrara Chalk in the Sand Wash Basin is characterized by having more terrigenous components than the Niobrara Chalk further to the east. This difference in lithology affects reservoir quality and the potential of the chalk as a matrix-producing reservoir. The degraded reservoir does not appear productive as a shaleoil reservoir, but may be productive as a shale-gas reservoir in the deeper and hotter parts of the Sand Wash Basin. The major objective of this paper is to present a preliminary characterization of the Niobrara Chalk as a shale-gas system in the northwest Sand Wash Basin.
Country:
- North America > United States > Colorado > Moffat County (0.41)
- North America > United States > Wyoming > Campbell County (0.40)
Oilfield Places:
- North America > United States > Wyoming > Niobrara Formation (0.99)
- North America > United States > Wyoming > Laramie Basin > Niobrara Formation (0.99)
- North America > United States > Wyoming > Greater Green River Basin > Sand Wash Basin > Niobrara Formation (0.99)
- (10 more...)
SPE Disciplines:
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Shale gas (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Exploration, development, structural geology (1.00)
Comparison of Marcellus Fracturing Using Azimuthal Seismic Attributes Versus Published Data from Outcrop Studies
Inks, Tanya L. (IS Interpretation Services, Inc.) | Engelder, Terry (Pennsylvania State University) | Golob, Bruce (ION GXT) | Hocum, Jacki S. (ION GXT) | O'Brien, Darien G. (Solutions Engineering)
Summary Using a good quality northern Pennsylvania (PA) Analog 3D survey, available well data, published outcrop data and subsurface information as well as production data available from the state, we are able to demonstrate that wide-azimuth seismic is sensitive to variations in fracturing at the scale of individual pads or even individual wells. This variation in fracturing begins to explain why production varies significantly, even locally, within the Marcellus play. Rose diagrams from quantitative fracture analysis using azimuthal seismic velocity volumes are compared to published data from Appalachian black shale outcrops and subsurface fracture models proposed in various papers in order to validate the results from subsurface data. While it has long been understood that natural fracture systems are essential for achieving the best production in Marcellus shale gas wells, methodologies for understanding the heterogeneities in these fracture systems in the subsurface are less well understood. Analysis of wide-azimuth P-wave seismic velocity attributes at the reservoir level, and for specific laterals or proposed laterals, can provide this insight. Although anisotropy, measured as azimuthal variations in velocity, can reflect rock fabric or stress, we show evidence that the likely source of these anisotropies is the presence of systematic joints.
anisotropy, azimuth, basin, black shale, cherry valley, complex reservoir, diagram, Engelder, eur area, fracture, geological society, hamilton group, heterogeneity, marcellus, Pennsylvania, perpendicular, Reservoir Characterization, shale, subset area, University, Upstream Oil & Gas, variation, Vfast
Country:
- North America > United States > Pennsylvania (1.00)
- North America > United States > New York (0.90)
Geophysics:
- Geophysics > Seismic Surveying > Seismic Processing (1.00)
- Geophysics > Seismic Surveying > Seismic Modeling > Velocity Modeling (1.00)
- Geophysics > Seismic Surveying > Surface Seismic Acquisition (0.70)
Oilfield Places:
- South America > Chile > Magallanes > Magallanes Basin > Fell Block (0.99)
- North America > United States > Wyoming > Uinta Basin (0.99)
- North America > United States > Wyoming > Niobrara Formation (0.99)
- (41 more...)
SPE Disciplines:
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
Introduction The seismic characterization of the Niobrara presented here is based on recently acquired wide-azimuth 3D seismic data in Weld County, N.E Colorado (Figure 1), and publically available well data for calibration within the area. The presentation starts with the location and geologic setting of the Niobrara and its vertical reference to the seismic response (Figure 2). An association is made using geometric attributes relating the complex subtle faulting to the Laramide Orogeny, which occurred in a series of pulses with intervening quiescent phases, possibly influencing hydrocarbon production. This sets the local structural framework for using fracture anisotropy and related rock properties for locating possible areas of significant interest. The Niobrara Formation lies in a thermally mature fairway which today is the Denver-Julesburg Basin. These sediments were deposited in an ancient Cretaceous seaway (Western Interior Seaway) running in a north-south direction through the mid-western United States, with ends open to the ocean. The Niobrara is carbonate rich on the east side, where the study area is located producing oil, and clay rich on the west side of the Basin. The Smoky Hill Chalk Member is 300–400 ft thick and composed of three key limestones (chalk) benches A, B and C which are each approximately 30–40 ft. thick (Figure 2). They are named from their resistive nature as seen along cliff exposures, and are intercalated with organic rich marls, the source rock. URTeC 1576924
URTEC-1576924-MS
anisotropy, azimuth, brittleness, calcite content, complex reservoir, elastic inversion, estimation, impedance, information, inversion, Niobrara, orientation, p-and s-wave impedance, Poisson, prospecting, Reservoir Characterization, risk reduction, rock property, s-impedance, s-wave impedance, seismic data, unconventional niobrara play, Upstream Oil & Gas
Geophysics:
- Geophysics > Seismic Surveying > Seismic Processing (1.00)
- Geophysics > Seismic Surveying > Surface Seismic Acquisition (0.70)
- Geophysics > Seismic Surveying > Seismic Interpretation > Seismic Reservoir Characterization (0.49)
- Geophysics > Seismic Surveying > Seismic Modeling > Velocity Modeling > Seismic Inversion (0.31)
Oilfield Places:
- North America > United States > Wyoming > Niobrara Formation (0.99)
- North America > United States > Wyoming > Laramie Basin > Niobrara Formation (0.99)
- North America > United States > Wyoming > DJ (Denver-Julesburg) Basin > Niobrara Formation (0.99)
- (11 more...)
SPE Disciplines:
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
Niobrara Fracture Prospecting Through Integrated Structural and Azimuthal Seismic Interpretation, Silo Field Area, Wyoming
Treadgold, Galen (Global Geophysical Services) | Eisenstadt, Gloria (Global Geophysical Services) | Maher, John (Global Geophysical Services) | Fuller, Joe (Global Geophysical Services) | Campbell, Bruce (Global Geophysical Services)
Rock property analysis of the A large multi-client, full-azimuth 3D seismic survey of Niobrara involved processing the 3D to address both layer almost 800 square miles in southeastern Wyoming is the and azimuthal anisotropy, creating gathers with reliable far basis for a regional structural interpretation and azimuthal offset amplitudes for an elastic inversion. Initial analysis of velocity analysis of the Niobrara in the area of the Silo the layer anisotropy was performed on isotropicly migrated Field, in the northern end of the Denver-Jules Basin. The gathers using a simultaneous picking tool for velocity and unconventional Niobrara oil and gas play has been VTI (vertical transverse isotropy). VTI information was compared to the Bakken in North Dakota but variable well then used to update traveltimes and begin scanning for HTI results have long plagued operators. Silo Field has (horizontal transverse isotropy). The approach used to produced about 10 million barrels of oil since 1981 but well define the HTI involved migrating the gathers rates can vary drastically over a short distance. The study approximately 100 times to test the impact of small integrates seismically derived rock attributes, well and changes in azimuthal anisotropy (as expressed by elliptical production data, and integrated regional structural migration operators). The migration scanning result was interpretation to understand the Niobrara fracturing and to used to once again update 1-D travel times feeding a reduce drilling risk.
azimuthal seismic interpretation, basement, Basement Fault, basement thrust, deformation, fracture prospecting, inversion, main menu niobrara fracture prospecting, Niobrara, niobrara fracture prospecting, nw-se, Reservoir Characterization, seg las vegas 2012, Silo Field Area, Upstream Oil & Gas, wyoming
Geophysics:
- Geophysics > Seismic Surveying > Seismic Interpretation (0.51)
- Geophysics > Seismic Surveying > Seismic Processing > Seismic Migration (0.48)
- Geophysics > Seismic Surveying > Seismic Modeling > Velocity Modeling > Seismic Inversion (0.35)
Oilfield Places:
- North America > United States > Wyoming > Silo Field (0.99)
- North America > United States > Wyoming > Niobrara Formation (0.99)
- North America > United States > South Dakota > Williston Basin > Bakken Shale Formation (0.99)
- (13 more...)
SPE Disciplines: Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
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