The prediction of porosity is achieved by using ava ilable core and log data; however, the estimation of permeability is limited to the scare core data. Hence, porosity and saturation data through the framework of flow units can be used to make an esti mation of reservoir permeability. The purpose of this study is to predict the permeability of a c arbonate gas reservoir by using physical-based empirical dependence on porosity and other reservoi r rock properties. It is emphasized that this new relationship has a theoretical background and is ba sed on molecular theories. It is found out that if rock samples with different types are separated pro perly and samples with similar fluid-flow properties are classified in the same group, then t his leads to finding an appropriate permeability/porosity relationship. In particular, the concept of hydraulic flow units (HFU) is used to characterize different rock types. This leads to a new physical-based permeability/porosity relationship that has two regression constants whic h are determined from the HFU method. These coefficients, which are obtained for several rock t ypes in this study, may not be applicable to other carbonate rocks; but, by using the general form of the model presented here, based on the HFU method, one may obtain the value of these coefficie nts for any carbonate rock types. Finally, we used the data of cored wells for the validation of the permeability results.

https://ijogst.put.ac.ir/article_2772_187042433290b728bbb5bb235fd76805.pdf

A Physical-based Model of Permeability/Porosity Relationship for the Rock Data of Iran Southern Carbonate Reservoirs

Investigation of the effect of tortuosity, hydrocarbon saturation and porosity on enhancing reservoir characterization

T he giant Wilmington oil field of Los Angeles County, California, on production since 1932, has produced more than 2.6 billion barrels of oil from basin turbidite sandstones of the Pliocene and Miocene. To better define the actual hydrologic units, the seven productive zones were subdivided into 52 subzones through detailed reservoir characterization. The asymmetrical anticline is highly faulted, and development proceeded from west to east through each of the 10 fault blocks. In the western fault blocks, water cuts exceed 96%, and the reservoirs are near their economic limit. Several new technologies have been applied to specific areas to improve the production efficiencies and thus prolong the field life. Tertiary and secondary recovery techniques utilizing steam have proved successful in the heavy oil reservoirs, but potential subsidence has limited their application. Case history 1 involves detailed reservoir characterization and optimization of a steamflood in the Tar zone of Fault Block II. Lessons learned were successfully applied in the Tar zone, of Fault Block V (4000 m to the east). Case history 2 focuses on 3-D reservoir property and geologic modeling to define and exploit bypassed oil. Case history 3 describes how this technology is brought deeper into the formation to capture bypassed oil with a tight-radius horizontal well. Clarke, D. D., and C. C. Phillips, 2003, Three-dimensional geologic modeling and horizontal drilling bring more oil out of the Wilmington oil field of southern California, in T. R. Carr, E. P. Mason, and C. T. Feazel, eds., Horizontal wells: Focus on the reservoir: AAPG Methods in Exploration

AAPG Methods in Exploration No. 14, Chapter 3: Three-dimensional Geologic Modeling and Horizontal Drilling Bring More Oil out of the Wilmington Oil Field of Southern California

Summary Traditionally, measurement-while-drilling (MWD) data are used primarily for geosteering purposes and drilling decisions such as monitoring of hole direction, deviation, and delineation of abnormally pressured zones. Wireline resistivity measurements, galvanic and induction, play a fundamental role in identifying and delineating oil- and gas-bearing formations. The availability of both MWD and wireline data not only provides the interpreter with abundant information about subsurface formations but also poses a new challenge to generate a unique model(s) that better explains both data sets. Generally, MWD and wireline data are interpreted independently to estimate formation resistivities that may result in inconsistent earth models. In this study, we performed a joint inversion of MWD Multiple propagation resistivity (MPR), and wireline High Definition Induction log (HDIL) data to come up with an earth model that best explains bot the data sets. An inversion strategy using a dual earth model, that describes the appropriate logging conditions of both wireline and MWD was also used in theinversion. Finally, the proposed algorithm was implemented on synthetic and the Gulf of Mexico data examples, and the results were compared with conventional MPR and HDIL processing results.

Joint Inversion of MWD And Wireline Measurements

The world is gradually moving toward a severe energy crisis, with an ever-increasing demand for energy overstepping its supply. Therefore, the energy crisis in the world has shed important light on the need for enhanced oil recovery to provide an affordable energy supply. Inaccurate reservoir characterization may lead to the failure of enhanced oil recovery projects. Thus, the accurate establishment of reservoir characterization techniques is required to successfully plan and execute the enhanced oil recovery projects. The main objective of this research is to obtain an accurate approach that can be used to estimate rock types, flow zone indicators, permeability, tortuosity, and irreducible water saturation for uncored wells based on electrical rock properties that were obtained from only logging tools. The new technique is obtained by modifying the Resistivity Zone Index (RZI) equation that was presented by Shahat et al. by taking the tortuosity factor into consideration. When true formation resistivity (Rt) and inverse porosity (1/Φ) are correlated on a log–log scale, unit slope parallel straight lines are produced, where each line represents a distinct electrical flow unit (EFU). Each line’s intercept with the y-axis at 1/Φ = 1 yields a unique parameter specified as the Electrical Tortuosity Index (ETI). The proposed approach was validated successfully by testing it on log data from 21 logged wells and comparing it to the Amaefule technique, which was applied to 1135 core samples taken from the same reservoir. Electrical Tortuosity Index (ETI) values show marked accuracy for representing reservoir compared with Flow Zone Indicator (FZI) values obtained by the Amaefule technique and Resistivity Zone Index (RZI) values obtained by the Shahat et al. technique, with correlation coefficients of determination (R2) values equal to 0.98 and 0.99, respectively. Hence, by using the new technique, the Flow Zone Indicator, permeability, tortuosity, and irreducible water saturation were estimated and then compared with the obtained results from the core analysis, which showed a great match with the R2-values of 0.98, 0.96, 0.98, and 0.99, respectively.

https://pubs.acs.org/doi/pdf/10.1021/acsomega.3c00904

Electrical Tortuosity Index: A New Approach for Identifying Rock Typing to Enhance Reservoir Characterization Using Well-Log Data of Uncored Wells

Flow Quality Indicator (FQI): An Innovative Approach to Permeability Prediction

New Methods Improve Interpretation Of Propagation Resistivity Data

Inflow Fluid Typing in Screened Horizontal Completions Using aPulsed Neutron Holdup Imager

Creating Opportunities from Challenges in a Difficult Environment: The Role of the Petrophysicist

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