Real‐time hydraulic fracture diagnostic imaging—using a multi‐level, multi‐component, large aperture seismic receiver

Walter, L.; Zinno, R.J.; Urbancic, Ted

doi:10.1190/1.1815761

Cited by 3 publications

(2 citation statements)

References 2 publications

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“…Microseismic events were localized using two techniques, Gayger's hypocenter method and a proprietary new tomography method developed by "Central Geophysical Expedition" [5,8,9]. That method allows determining the fracture geometry characteristics.…”

Section: Vsp Data Processingmentioning

confidence: 99%

Complex Fracture Geometry Investigations Conducted on Western-Siberian Oilfields at Rosneft Company

Никитин¹,

Shirnen²,

Manière³

2007

Proceedings of SPE Annual Technical Conference and Exhibition

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Section: Vsp Data Processingmentioning

confidence: 99%

Complex Fracture Geometry Investigations Conducted on Western-Siberian Oilfields at Rosneft Company

Никитин¹,

Shirnen²,

Manière³

2007

Proceedings of SPE Annual Technical Conference and Exhibition

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“…[1][2][3][4] With telemetry improvements and the limitation of economics, conventional practice has evolved to multiple receivers in a retrievable tool array located in an offset well. 2,5,6 The offset monitoring well is preferably a new, unperforated well, generally as close to the treatment well as possible and offset perpendicular to the fracture plane, based on prior estimates of fracture azimuth. In practice, a workover may be required on an offset producer, possibly requiring a bridge plug over existing perforations to minimize background noise.…”

Section: Introductionmentioning

confidence: 99%

Logging Tool Enables Fracture Characterization for Enhanced Field Recovery

Bailey

Sorem

2005

SPE Annual Technical Conference and Exhibition

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TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractExxonMobil has developed a fracture mapping tool that uses acoustic methods to infer the geometry of induced hydraulic fractures. This tool may be run in the treatment well during fracturing, or it can be used in one or more offset monitoring wells. This tool, "TABS" for Triaxial Borehole Seismic, consists of an array of three triaxial geophone receivers, a telemetry sub to transmit the data to surface in real time on conventional 7-strand wireline, and an interface to a Gyrodata survey tool to provide the tool orientation when clamped. The tool subs are interconnected with "flex links" that are rigid in rotation but flexible in bending to allow each clamp arm to make independent coupling to the wellbore casing. The overall design is that of a logging tool, facilitating application via wellhead lubricators.The geometry of the stimulated fracture has a significant impact on well productivity and recovery.In many applications, the reservoir depletion pattern is highly dependent on this geometry. Some key interactions between productivity and fracture geometry include:• Well spacing is determined by the fracture length, formation properties, and depletion plan.• Within this spacing constraint, well locations are determined by the induced fracture azimuth. Wells are placed to reduce interference among producers and to maximize conformance.• Fracture height growth out of zone may lead to more costly stimulation treatments and lower well productivity.Modifications to the treatment design and adjustments to the selection of perforated intervals may increase well performance.Working with the ExxonMobil Production Company, the TABS tool has been used to monitor 32 fracture treatments in 16 well entries.Results from several of these field applications will be used to describe the TABS technology and to demonstrate fracture geometry measurements.

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Complex Fracture Geometry Investigations Conducted on Western-Siberian Oil Fields at Rosneft Company

Никитин¹,

Shirnen

Manière

2007

SPE Annual Technical Conference and Exhibition

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The generalization of Hydraulic fracturing in West Siberia and the increase of job size over the recent year can impact the field development strategy. The correct estimation of the fracture dimension is critical to maximize the recovery factor of heterogeneous reservoir developed with water flood. Three main uncertainties exist: fracture height, half-length and azimuth. Commercial fracture models provide length estimate once a reliable estimate of height is known. This is evident for 2D model which requires a direct knowledge of the height but also for p3D model where the height is indirectly obtained from coupling stress profile and fluid flow. Fracture azimuth is traditionally provided by the horizontal stress anisotropy from open hole sonic logging. Unfortunately, in West Siberia at depth of 2500–3000 meters, there is negligible tectonic and open hole sonic dipole did not provide obvious fracture orientation. Fracture height growth affect mostly fracture job size and cost. Height growth has also shown to be a cause of premature wellbore screen out. Fracture half-length and orientation can have a significant impact on the effectiveness of pressure maintenance and flood efficiency. A review of world publication of direct fracture geometry measurement has shown the validity of seismic methods and tilt indicators for tight rock, such as carbonates and tight sandstone. However, all experiments on soft sandstones, such as found in West Siberian, have shown more limited results. Given the uncertainties in effective Fracture geometry and the negative impact that they could have on the field development, Rosneft decided to invest in a field research study denominated Fracture Geometry Investigation, to validate various method offered by the service industry. Two basic methods were tested and combined: wellbore logging and passive seismic. Wellbore logging is used to obtain an estimate of wellbore fracture height. It combines temperature log immediately after Minifrac or after Frac and Cased Hole Sonic Anisotropy (CHSA) which can be run at any time after frac. The direct estimate of fracture height is used to validate the result of a calibrated HF simulator using Net Pressure matching analysis. Passive Seismic monitoring (PSM) is used to obtain direct estimate of height, length and azimuth. PSM Acquisition must be done during hydraulic fracturing from the nearest well. The main goal of this study was to validate each method's effectiveness and to construct a calibrated fracture model for the particular reservoir under investigation. The results of this investigation will be used to optimize fracture design, pressure maintenance strategy and pattern orientation. Fields and Reservoir Description The Priobskoe field, one of the largest oilfields in the world, is located in Western Siberia. The reservoirs under production are part of Cherkashinskaia set of rock [1, 2] composed of shales, siltstones and sandstones. 90% of the production for the Priobskoe oilfield comes from AC-10, AC-11 and AC-12. The main focus of this paper is on the AC-11 and AC-12 formations, where production development and enhancement activities have started in 2000. The AC-11 formation consists of laminated oil saturated sandstone. The average permeability of AC-11 formation is 8mD, and the porosity is 13–16%. The average oil saturation is 50–60% with reservoir pressure at 248 bars. The AC-12 formation situated below the AC-11 is characterized by complex and aerial heterogeneous structure of several sandstone bodies, which complicates HF application. AC-12 is oil saturated highly laminated sandstone with shale streaks in between. The average permeability of AC-12 formation is 1 to 2 mD, and the porosity is 14–18%. The average oil saturation is 50–66%, and the reservoir pressure about 255 bars. Malobalykskoe field is a large oilfield of West Siberia with a majority of reserves (about 80%) concentrated in Achimovskaya, a formation from the Cretaceous period. Formation BS16–22 of Achimovskaya is well developed covering all the area and is represented by alternation of sandstones, siltstones and argillites. This reservoir is separated from upper layer by clay bed with thickness from 1.4 to 86 meters. A cross-section of BS16–22 formation shows from 8 to 23 permeable layers. Average number of such layers is 10.8 with about 2 mD permeability and initial reservoir pressure of 278 bars.

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Real‐time hydraulic fracture diagnostic imaging—using a multi‐level, multi‐component, large aperture seismic receiver

Cited by 3 publications

References 2 publications

Complex Fracture Geometry Investigations Conducted on Western-Siberian Oilfields at Rosneft Company

Complex Fracture Geometry Investigations Conducted on Western-Siberian Oilfields at Rosneft Company

Logging Tool Enables Fracture Characterization for Enhanced Field Recovery

Complex Fracture Geometry Investigations Conducted on Western-Siberian Oil Fields at Rosneft Company

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