Nuclear Magnetic Resonance Log Evaluation of Low-Resistivity Sandstone Reservoirs By-Passed by Conventional Logging Analysis

Hamada, G.M.; Al-Blehed, M.S.; Al-Awad, Musaed N.J.

doi:10.2118/64406-ms

Cited by 11 publications

(5 citation statements)

References 4 publications

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“…Then the correlation result in the following transform. 2 1 708 T Pc = C=708 Average C =800 is considered as the arithmetic mean of the above two values in case of OBM. So the average correlation between PC and T2 is…”

Section: Model Calibrationmentioning

confidence: 99%

“…The aiming is to establish facies independent porosity and permeability models and avoid using lithology independent T2 cut-off (1) The advantage of NMR tool is sensitive only to hydrogen and fluid protons and no borehole correction is needed whenever the radius of investigation is beyond caliper measurements specially incase of MRIL tool (2) .…”

Section: Introductionmentioning

confidence: 99%

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Integration of NMR with Other Open Hole Logs for Improved Porosity, Permeability and Capillary Pressure of Gas Sand Reservoirs

Hamada

Oraby

Abushanab³

2007

All Days

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TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractAnalysis of tight gas sand reservoirs is one of the most difficult problems. Many tight formations are extremely complex, producing from multiple layers with different permeability that is often enhanced by natural fracturing. Therefore, looking for using new well logging techniques like NMR in individual bases or in combination with conventional open hole logs and building new interpretation methodology is essential to well define and obtain the representative reservoir characterizations.Nuclear magnetic resonance (NMR) logs differ from conventional neutron, density, sonic and resistivity logs because the NMR measurements provide mainly lithology independent detailed porosity and a good evaluation hydrocarbon potential. NMR logs can be used to determine formation permeability and capillary pressure.This paper concentrates on three petrophysical applications of NMR; 1) present a technical method for porosity calculation in which density and NMR porosities are combined and calibrated to core, 2) Use new empirical method of bulk gas volume (BG) in the invaded zone for permeability estimation termed BGMRK and 3) Use T 2 distribution for capillary pressure approximation and correct pore size distribution for gas.These applications of NMR logs have been applied in a gas sand reservoir field of different facies and permeability varies from less than 0.1md to more than 100md related to facies changes. These applications result in a) The technique of using combined NMR and bulk density data significantly reduces uncertainty in porosity through elimination of the neutron log down to 0.5%. b) The new approach of "BGMRK" resulted in very simple facies independent model to calculate reliable permeability 2. c) Capillary pressure can be approximated from NMR T2 distribution and then the integration between cap-curves and T 2 distribution can be corrected for partial pores fluid fill.

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Section: Model Calibrationmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Integration of NMR with Other Open Hole Logs for Improved Porosity, Permeability and Capillary Pressure of Gas Sand Reservoirs

Hamada

Oraby

Abushanab³

2007

All Days

Self Cite

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“…While each method is a powerful subsurface-mapping tool, they do have limitations such as overlapping range of resistivity values of different materials such as clay and shale, but in this case, the materials could be differentiated using seismic refraction method due to different density of the materials. 2 In contrast, when the higher density upper subsurface layer is underlain by a lower density layer, seismic refraction method cannot distinguish the between the two layers but these layers could be distinguished by resistivity method. 3 A way to play around the limitations is by combining inversion data from both methods via closure coupling to generate an enhanced model where one model influences the other model.…”

Section: Introductionmentioning

confidence: 99%

Mapping Buried Alluvial Layer Using Integrated Seismic Refraction and 2-D Resistivity Inversions at Sungai Batu, Kedah, Malaysia

Yusoh¹,

Rosli²,

Rahman³

et al. 2020

JPS

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Resistivity and seismic refraction are conventional methods in preinvestigations of subsurface structures, which are commonly employed and interpreted separately to reduce ambiguities from each method. Although integration of the two methods' models into a single model was recently introduced, the integration still requires enhancement to generate an accurate subsurface profile. Therefore, an enhanced algorithm called closure coupling technique was developed to integrate 2-dimensional (2-D) models of resistivity and seismic refraction to become a single integrated model where one model influences the other model. The resultant integrated model is superior in mapping the subsurface compared with singular resistivity and seismic models. These methods were then applied on a pre-investigative field dataset in finding ancient river for archaeological point of interest. Due to complex geology, only slight changes were observed in the inverted model of the integrated data inversion for this archetype. Still, the combined model enhanced subsurface interpretation by highlighting the distribution of buried alluvial soil.

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“…The uncertainty associated with identification of the proper porosity and permeability model for each unit is high, which could result in high permeability estimation far beyond the actual well performance. Therefore, integration of nonstandard tools such as nuclear magnetic resonance (NMR) with conventional tools and SCAL in the petrophysical evaluation is essential to reduce the uncertainty beyond the limitations of each tool in individual bases, especially in gas reservoirs (Coates et al, 1997;Minh et al, 1998;Hamada et al, 2000). Freedman et al (1998) proposed a combination of density porosity and NMR porosity (f DMR ) to determine gas corrected formation porosity and flushed zone water saturation (S xo ).…”

Section: Introductionmentioning

confidence: 99%

Integrated NMR and Density Logs For Evaluation of Heterogeneous Gas-Bearing Shaly Sands

Elmahdy

Hamada

2014

Petroleum Science and Technology

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Petrophysical properties evaluation of heterogeneous gas shaly sands reservoirs is one of the most difficult problems. These reservoirs usually produce from multiple layers with different permeability and complex formation, which is often enhanced by natural fracturing. Therefore, using new well logging techniques such as nuclear magnetic resonance (NMR) or a combination of NMR and conventional openhole logs, as well as developing new interpretation methodologies are essential for improved reservoir characterization. NMR logs differ from other conventional logs. Integration of NMR logs, density logs, and core data shall minimize uncertainties in the determination of formation porosity, permeability, and capillary pressure curve. The authors concentrate on determination of three petrophysical parameters of heterogeneous gas sand reservoirs: (a) determination of DMR porosity, DMR , which is deduced from NMR porosity and density porosity; (b) NMR permeability, K BGMR , which is based on the dynamic concept of gas movement and bulk gas volume in the invaded zone; and (c) capillary pressure, which is derived from relaxation time T 2 distribution.

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Nuclear Magnetic Resonance Log Evaluation of Low-Resistivity Sandstone Reservoirs By-Passed by Conventional Logging Analysis

Abstract: TX 75083-3836, U.S.A., fax 01-972-952-9435.

Cited by 11 publications

References 4 publications

Integration of NMR with Other Open Hole Logs for Improved Porosity, Permeability and Capillary Pressure of Gas Sand Reservoirs

Integration of NMR with Other Open Hole Logs for Improved Porosity, Permeability and Capillary Pressure of Gas Sand Reservoirs

Mapping Buried Alluvial Layer Using Integrated Seismic Refraction and 2-D Resistivity Inversions at Sungai Batu, Kedah, Malaysia

Integrated NMR and Density Logs For Evaluation of Heterogeneous Gas-Bearing Shaly Sands

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