The Integration of Petrophysical and Formation Tester Data in the Creation of a Petrophysical Model for an Eastern Siberia Oilfield

Karpekin, Yevgeniy; Weinheber, Peter; Abdrakhmanova, L.; Tsiklakov, Alexander; Gordeev, Yaroslav Ignatievich; Maslov, S. A.

doi:10.2118/146043-ms

Cited by 3 publications

(1 citation statement)

References 9 publications

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“…The permeability scale analysis for the upper and lower carbonates in this well reflects the positive effect of the dolomitization in the lower zone flow characteristics. Karpekin et al (2011) indicate that, in the development of a petrophysical model, some specific aspects can complicate the determination of porosity and permeability. Some of these are the effects of pore throat plugging, the difficulty to resolve permeability predictions from logs even with a comprehensive suite and extensive core data, and the final determination of the fluid contacts.…”

Section: Log-based Permeability Calibration With Interval Pressure Trmentioning

confidence: 99%

Carbonate Reservoir Characterization at Different Scales: Proving the Value of Integration

et al. 2013

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Much has been written about carbonate reservoir complexities, heterogeneity, and data integration at different scales. However, there are not many published examples that show a comparison of producibility modeling predictions and actual field results that include data from core, advanced openhole well logs, formation testers, and drillstem tests.In this study, we present the integration of data and measurements from advanced technologies to evaluate reservoir heterogeneity of carbonate formations on multiple scales. Quantitative textural analyses based on a comprehensive suite of petrophysical logging measurements were integrated with core data and formation testing data to characterize hydrocarbon/water transition zones and formation permeability and producibility. The offshore carbonate reservoir studied is composed of limestones and dolomites. Despite the inherent chemical complexities and hidden modes of origin, dolomites often exhibit favorable reservoir quality with high porosity and permeability properties. For this reason, E&P companies continue to predict where drilling targets are most likely to encounter these sweet spots.Traditional permeability correlations are not effective in these systems, leading to overdependence on porosity-based reservoir descriptions to predict fluid flow. Using nonparametric regression, we have established a relationship between permeability and porosity from logs that are available fieldwide. Subsequent integration of this data with interval pressure transient test data in zones selected based on the observed rock heterogeneity enables further optimization of the final permeability correlation. The descriptions of the field examples confirm the success of this integrated approach and include the planning, real-time monitoring, and final validation of permeability and anisotropy at different scale during the exploration phase of a field.Selecting the well locations for development using the proposed approach has proved valuable for improving field development practices. The results have led to enhanced reservoir characterization based on flow (permeability) and storagecapacity analyses (porosity partitioning), and a better understanding of the reservoir heterogeneity at different scales; the results have been used to improve drillstem test designs and reservoir production strategies.

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Section: Log-based Permeability Calibration With Interval Pressure Trmentioning

confidence: 99%

Carbonate Reservoir Characterization at Different Scales: Proving the Value of Integration

et al. 2013

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Experience of Application of Extended Logging Suite and Formation Testers for characterization of Jurassic Age Deposits of the Em-Egovsky Field

Martinov¹,

Kozlov²,

Platunov³

et al. 2013

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In a recent Em-Egovskoe well an extended logging suite was performed with the aim to evaluate the petrophysical properties of Jurassic and Paleozoic formations as well as to improve the structural geological model of this part of the oilfield and to do detailed characterization of the dynamic model by desired properties of formations and fluids. Apart from a standard "triple combo" logging suite the following advanced technologies were applied in the well: neutron-gamma spectroscopy, nuclear magnetic resonance, formation micro imager, formation testers in different modes of reservoir and fluid properties evaluation. Noteworthy, the zone of interest was considered to contain only oil-saturated reservoirs – no gas cap was expected. Indeed on the initial triple combo log data there were no routine gas attributes were observed. Gas-saturated reservoirs were only observed based on integrated analysis of standard and advanced log data, particularly, nuclear magnetic resonance and cross-dipole sonic measurements. Gas-saturated intervals were fully proven by formation tester using downhole fluid analysis (DFA) As a result, one of the Jurassic layers was acknowledged as gas/gas-condensate saturated down to the bottom and the rest of Jurassic intervals were found to be oil saturated. The Abalak formation was also encountered in this well and evaluated. Thin carbonate streaks were identified with the micro-imager and were tested with the dual-packer module of the wireline formation tester. The result was the first ever Abalak oil sample in this field. Furthermore, based on pressure transient analysis of the build-up from the pressure test it was suggested that these tight streaks are laterally discontinuous. Finally, we created a stress profile in the Jurassic and Paleozoic layers. Based on formation micro-imager and acoustic scanning measurements the maximum horizontal stress directions and magnitudes were estimated. Then dual-packer formation tester micro-stress measurements were made to acquire direct measurements of fracture closure pressure. These measurements were used to calibrate our stress model.

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Performance Analysis Of Different Formation Testing Technologies In Complex Carbonate Reservoirs Of West Kazakhstan

et al. 2016

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Objectives & Scope The case study presents an application and comparison of different wireline formation testing technology to acquire vital pressure data and downhole fluid samples in tight sub-milidarcy heterogeneous carbonate fields. Examples from Kazakhstan, where tools with different configuration of fluid intake positions and shapes, various flowing areas, are presented to allow us to compare and contrast the performance of each in more complex and challenging reservoir conditions. Methods, Procedures, Process First part of the study discusses the comparison between inflatable straddle packer and radial probe in terms of their data quality and efficiency of the acquisition, where both of the tools were deployed to measure formation pressure, conduct downhole fluid analysis and acquire downhole fluid samples. While the second part focuses on comparison between single probe and radial probe, where both of them were deployed in the well together and were intended to get formation pressure measurements in the zones with the lowest porosity. Results, Observations, Conclusions Extreme downhole conditions pose a challenge to formation testing, acquisition of accurate reservoir pressure data and representative formation samples have proved difficult in cases of highly heterogeneous low porosity and low permeability reservoirs. In the first part of the study, the performance of the each tool compared with different observations such as: average time to first hydrocarbon, average volume to first hydrocarbon, water fraction content, and sampling and downhole fluid analysis by formation zones and by mobility ranges. In the second part, the study elaborates on pressure survey conducted in tight highly heterogeneous carbonate reservoir, where tool with large flowing area and circumferential flow shows its superiority, thus improving operator's reservoir evaluation. Downhole positions of both tools against formation features, such as vugs, porous spots and anhydrite inclusions, were reconstructed on microimager log. Novel/Additive information This case study describes and compares the approaches and methodologies to acquire and perform complex interpretation of critical formation pressure data in heterogeneous carbonate reservoir. The learnings from this successful acquisition and interpretation can substantially improve the reservoir characterization of similar fields worldwide.

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The Integration of Petrophysical and Formation Tester Data in the Creation of a Petrophysical Model for an Eastern Siberia Oilfield

Cited by 3 publications

References 9 publications

Carbonate Reservoir Characterization at Different Scales: Proving the Value of Integration

Carbonate Reservoir Characterization at Different Scales: Proving the Value of Integration

Experience of Application of Extended Logging Suite and Formation Testers for characterization of Jurassic Age Deposits of the Em-Egovsky Field

Performance Analysis Of Different Formation Testing Technologies In Complex Carbonate Reservoirs Of West Kazakhstan

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