perISPGمجله زمین شناسی نفت ایران 2251-87382251-87382025-111428118articleSeyed Ehsan EbrahimiPetroleumg_ee@yahoo.com1Bahman Soleimanisoleimani_b@scu.ac.ir2Dept. of Petroleum Geology and Sedimentary Basins, Shahid Chamran University of Ahvaz Prof. of the Department of Petroleum Geology and Sedimentary Basins, Shahid Chamran University of Ahvaz, Ahvaz, Iran.<p>One of the most important characteristics of a reservoir is the pressure of hydrocarbon fluids, which plays a very important role in the daily production and the final recovery rate of hydrocarbons. Therefore, knowing the pressure changes of each field over time is very important in the management and development of the reservoir. In the present study, the subsurface data of Asmari-Pabdeh reservoir in 30 wells of one of the oil fields in the southwest were used. In this research, geological data; Petrophysical parameters; fluid contact surfaces; production history from the reservoir; drawing hydrodynamic maps; And the ratio of gas to oil production (GOR) was investigated in the ArcGIS software environment.</p> <p>Using ArcGIS 9.2 software, the oil pressure on the surface of the field and over time for different years, including the period before and after the gas injection project, was investigated and it was concluded that the carbonate reservoir of this field has many fractures and with Paying attention to the amount of fractures, their expansion as well as porosity and permeability, different parts of the field have a very good fluid connection with each other, fluid pressure in the whole field is almost uniform and has minor changes. Due to the natural drift mechanism of the field, the pressure drop resulting from the production was severe, but the efficiency of the gas injection project was successful in a way that it has been very effective in maintaining the pressure and increasing oil recovery. Hydrodynamic force is the most important factor in the fluid displacement mechanism for hydrocarbon production and is one of the effective mechanisms with a high recovery factor. This type of studies can be a useful and powerful tool for managing the production and development and control of extraction of oil and gas reservoirs.</p>http://journal.ispg.ir/Article/44365Asmari reservoir oil recovery hydrodynamic map gas injection drive mechanism ArcGIS softwareperISPGمجله زمین شناسی نفت ایران 2251-87382251-87382025-1114281942articleSeiedAghil Hoseinisa_hoseini_609@yahoo.com1Davood Jahanijahani_davood@yahoo.com2Nader Kohansal Ghadimvandn_k_ghadimvand@iau.tnb.ac.irr3Department of Geology , North Tehran Branch, Islamic Azad University, Tehran, IranDepartment of Geology, North Tehran Branch, Islamic Azad University, Tehran, Iran<p>The Fahliyan Formation, of Lower Cretaceous age (Berriasian-Barremian), is one of the important hydrocarbon reservoirs in southwestern Iran. This study focuses on the Fahliyan Formation in a well located in the Jufair oil field in the Abadan plain, aiming to reconstruct the depositional environment, sea level fluctuations, and diagenetic history. To achieve this, 250 thin sections were analyzed for petrographic characteristics. In addition, changes in petrophysical gamma, neutron, and density logs were examined to complement the microscopic results. In the studied well, 12 sedimentary facies from open marine, shoal, lagoon, and tidal sub-environments were identified. The distribution of facies shows that they have deposited in the outer, middle, and inner parts of a homoclinal carbonate ramp. Diagenetic processes in different meteoric, marine, and burial environments have affected the sediments of the Fahliyan Formation. Physical compaction and cementation processes have played the most role in reducing porosity, while dolomitization, stylolitization, and fracturing processes have increased porosity. Analysis of sea level fluctuations during the deposition of the Fahliyan Formation within the framework of sequence stratigraphy revealed two third-order sedimentary sequences in the well, mostly composed of highstand system tract. Reservoir quality assessments indicated that the shoal and tidal flat facies within the highstand system tracts exhibit the highest porosity.</p>http://journal.ispg.ir/Article/48807Sedimentary environment Diagenetic processes Sequnce stratigraphy Fahliyan Formation Abadan Plain Jufair FieldperISPGمجله زمین شناسی نفت ایران 2251-87382251-87382025-1114284363articlefirozeh balaghatifbalaghati76@icloud.com1Ali Bahramibahramigeoui@gmail.com2Hosyen Vaziri moghadamavaziri7304@gmail.com3Hamed Ameriameri.hamed@gmail.com4Yazdi YazdiMeh.yazdi@gmail.com5Gustavo Gabriel Voldmangvoldman@unc.edu.ar6Department of Geology, University of IsfahanDepartment of Geology, University of Isfahan, Department of Ecology, Institute of Science, High Technology and Environmental Science, professorPhD Stratigraphy and Paleontology, Centro de Investigaciones en Ciencias de la Tierra (CICTERRA), CONICET, Universidad Nacional de Córdoba, X5016GCB Córdoba, Argentina<p>Ordovician marine sedimentary sequences occur in several structural blocks widely in Iran, along the northern margin of Gondwana. In north Kerman province, the Ordovician deposits are known as the Katkoyeh Formation, which includes 70 to 300 meters of siliciclastic rocks with rare and thick pyroclastic carbonate layers in its upper part. In order to better percise biostratigraphy of the Katkoyeh Formation in Kerman region, systematic sampling for conodonts was carried out in Asyab-valley section, located about 12 km southeast of Zarand city, the thickness of Ordovician deposits in the studied section is 154/4 meters. The Ordovician deposits of Katkoyeh Formation in the studied section includes silty shales, diabase, pilolava, basaltic tuffs, red sandstone, marl, limestone and sandy limestone. After sampling and recovery of conodonts, a total of nearly 680 conodont elements were obtained from the studied samples, a total of 14 genera and 21 species of conodonts were discriminated. Based on the occurrence of biostratigraphically important species, three conodont ranges have been recorded. These three biozones are:</p> <p>1) <em>Rossodus manitouensis/Paltodus deltifer</em> Concurrent Range Zone (the lowest part of Late Tremadocine; Early Ordovician)</p> <p>2) <em>Juanognathus variabilis</em> Range Zone (Fluvian; Early Ordovician)</p> <p>3) <em>Icriodella superba</em> Range Zone (Katian - ? Hirnantian; Late Ordovician)</p> <p>Considering the CAI (5) of recovered conodont elements, the region has a high thermal history and the presence of hydrocarbon materials in the deposits of this area is ruled out.</p>http://journal.ispg.ir/Article/48721Ordovician Katkoyeh Formation northwest Kerman basin Asyab-valley Katkoyeh ZarandperISPGمجله زمین شناسی نفت ایران 2251-87382251-87382025-1114286479articleBabak Samanisamani.babak@gmail.com1Yaghoub Jalilijalili.y@scu.ac.ir2Negar MollaeiMollaei.N.1380@gmail.com3Faculty of Earth sciences, Shahid Chamran University of AhvazFaculty of Earth Sciences, Shahid Chamran University of Ahvaz<p>In this study, using interpreted seismic profiles, the geometric nature of folding and quantitative strain values ​​in the Asmari carbonate horizon in the Kupal oil field have been investigated. For this purpose, thirteen seismic profiles from the Kupal oil field were evaluated. By extracting the Asmari carbonate horizon from each seismic profile, initial data were prepared for geometric investigation of the fold style elements and strain analyses. Examination of fold style elements in the Asmari horizon of the Kupal oil field indicates an asymmetric fold with an interlimb angle of 110 to 147 degrees (gentle to open fold), an aspect ratio of 0.15 to 0.38 (broad to wide fold), and a bluntness ratio of 0.45 to 0.7 (sub rounded fold). In order to determine the values ​​of shortening and relative values ​​of strain using artificial intelligence, each of the seismic profiles was balanced and the values ​​of the initial length of the Asmari horizon were determined. The results show different shortening values ​​in different parts of the anticline. The shortening values ​​were calculated in the range of 2.67 to 8.65 percent and the strain ratio values ​​in the range of 1.05 to 1.19.</p>http://journal.ispg.ir/Article/50117Seismic profile Balanced cross section Fold aspect ratio Strain ratio Shortening percentage.perISPGمجله زمین شناسی نفت ایران 2251-87382251-87382025-1114288095articleMohammad Goodarzimohammadgoodarzi45@yahoo.com1Hassan Amiribakhtiaramiribakhtiarh.g3970@gmail.com2kheyrolah NuraeinejadKH.nuraei@gmail.com3Mostafa Sedaqgatneiamostafasedaghat1364@gmail.com4Department of Geology, Faculty of Sciences, Lorestan University, Khorramabad, IranAssociate professor, National Iranian South Oil Company (NISOC), Ahwaz, Iran.Ph.D. Student, Sedimentology and Sedimentary Petrology, Department of Geology, Faculty of Science, Shahid Beheshti UniversityPh.D. Student, Sedimentology and Sedimentary Petrology, Bu-Ali Sina University, Hamadan, Iran.<p style="text-align: left;"><strong>In this research, the upper part of Pabdeh Formation and the lower part of Asmari Formation were studied in two wells of Marun</strong> <strong>oil field. Based on the previous biostratigraphic studies, the age of the upper part of Pabdeh Formation is Late Eocene and the lower part of Asmari Formation is Oligocene. Based on the cyclostratigraphy study, using cyclolog software, five negative boundary levels (NB) and four positive boundary levels (PB) were identified and based on these boundary levels, four sedimentary cycles were determined.</strong> <strong>Boundary levels and sedimentary cycles identified in these wells corresponded to biological boundaries or maximum sea level. Based on the study, the first sedimentary cycle (NB1000-PB1000) Corresponding to the late Eocene/Oligocene time interval., the second sedimentary cycle (NB2000-PB2000) corresponding to Ruplin-Chattian-Chattian, the third sedimentary cycle (NB3000-PB3000) and the fourth sedimentary cycle (NB4000-PB4000) were identified</strong></p> <p><strong>Key words: Cyclolog, cyclostratigraphy, NB &ndash; PB Boundary surfaces,</strong><strong> Pabdeh formations, Asmari formation, Marun oilfield and </strong><strong>Cyclolog.</strong></p>http://journal.ispg.ir/Article/50091Cyclolog cyclostratigraphy NB – PB Boundary surfaces Pabdeh formations Asmari formation Marun oilfield and Cyclolog.perISPGمجله زمین شناسی نفت ایران 2251-87382251-87382025-11142896106articleHamed Amraeihamedamraei0@gmail.com1<p>Determining rock types and calculating the elastic and strength parameters of formations are among the most fundamental and complex petrophysical&ndash;geomechanical parameters in hydrocarbon reservoirs. Their accurate calculation forms the basis for many petroleum engineering and reservoir geomechanics studies. To this end, in the first stage of the present research, the optimal number of electrofacies was obtained for the studied well using a multi-partition clustering method based on the MRGC<a href="#_ftn1" name="_ftnref1">^[1]</a> graph, derived from a combination of geological data and both conventional and synthetic logs, including VDL<a href="#_ftn2" name="_ftnref2">^[2]</a> and NDS<a href="#_ftn3" name="_ftnref3">^[3]</a>. The proposed algorithm incorporates lithology effects and porosity types into calculations for accurate reservoir grouping. At this stage, five optimal electrofacies classes and groups were identified for the studied well using the MRGC-based clustering method. In the second stage, considering that calculating and estimating elastic and rock strength coefficients is essential in geomechanical studies &ndash; and since core data is not available throughout the entire well &ndash; calculations were made for Young&rsquo;s modulus, Poisson&rsquo;s ratio, bulk modulus, shear modulus, and uniaxial compressive strength using dipole sonic imaging (DSI) logs. The comparison of calculated elastic moduli and strength parameters with variations in the lithology column and porosity from petrophysical evaluation and core data confirms that as core and log porosity increase, the values of elastic moduli and strength parameters decrease. Hence, porosity has an inverse relationship with elastic moduli and strength parameters. In the present study, the correlation coefficient between the calculated bulk modulus and porosity was found to be (R² = 0.82), shear modulus (R² = 0.73), Young&rsquo;s modulus (R²= 0.77), Poisson&rsquo;s ratio (R² = 0.049), uniaxial compressive strength (R² = 0.84), and uniaxial tensile strength (R² = 0.65).</p> <p>&nbsp;</p> <p><a href="#_ftnref1" name="_ftn1">[1]</a> Multi-resolution graph-based clustering</p> <p><a href="#_ftnref2" name="_ftn2">[2]</a> Velocity Deviation Log</p> <p><a href="#_ftnref3" name="_ftn3">[3]</a> Neutron- Density Separation</p>http://journal.ispg.ir/Article/50617Reservoir Grouping Multi-Resolution Graph-Based Clustering Elasticity and Strength Parameters