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Evaluation of Al Hawaz Reservoir using Core Sample Analysis and Petrophysices Study in )O), Oil Field, Concision NC 115, Morzuq Basin.

The O field which belongs to Akakus Oil Operation which is located in north north west (NNW) of Murzuq basin , NC 115 Concession, It is 30 km west of Awbari. The main objectives of this study were to provide for the reservoir model of the Hawaz Formation: A detailed sedimentological and fracture description with the identification of significant stratal boundaries, maximum flooding surfaces, discontinuities and other internal structures of the supplied core, The description included determination of the lithology, grain-size, sorting, color, sedimentary structures, bed contacts, abundance of clay, degree of bioturbation and the presence of fossils. To describe and characterise the vertical distribution of sedimentary facies and provide an interpretation of the depositional environments in terms of sequence analysis. Construct a depositional model, based on regional knowledge and relevant data integration. A petrographic description on selected samples, including SEM and XRD analysis, to characterise detrital and authigenic mineral composition, internal fabric and diagenetic processes of identified facies, in relation to porosity and permeability. The reservoir is sealed by Tanezzuft shale, which is as a source rock also The porosity of this reservoir sandstone ranges between 11 to 15 % ,The water saturation is from 11 to 15 %. also based on petrophysices method, I have selected one well study to support the results that obtained from petrography study to get more results such as lithology identification, porosity ,permeability and mineral composition also to calculate the reservoir properties such as volume of shale, water and oil saturation, oil water contact and reservoir reserves, the initial oil in place is 804 MMSTB and the recoverable reserve is 178.5MMSTB.
Rajab F. ElZaroug(8-2022)
عرض

Assessment of the thermal maturation, organofacies, and petroleum generation history of Sirte Shale Formation in Sirt Basin, Libya

The current study is conducted to investigate the upper Cretaceous (Campanian) Sirte shale Formation to better understand the regional abundance of the organofacies, thermal maturation levels, and the petroleum generation and expulsion histories during the geological time in one of the most important petroliferous basins in North Africa (Sirt Basin). Rock-Eval pyrolysis analysis of 988 samples in 56 wells that penetrated the Cretaceous section in the Sirt Basin was used to screen and study the geological and geochemical characteristics of the Sirte shale Formation. Multi-dimensional basin modeling, including 1D burial histories and 2D modeling approaches, was calibrated with %VRo and pyrolysis Tmax data to establish refined regional maturity of the Sirte shale Formation. By using the Rock-Eval data, the type, occurrence, and distribution of organofacies in time and space were investigated using analytical assessment procedures and present-day mapping, such as total organic carbon (% TOCp), hydrogen index (HIp), and kerogen transformation ratio (TRp) to define the lateral and vertical special variation. Key biological marker (biomarkers) data is used to determine their special types, abundance, and host sedimentary environments. We used integrated geochemistry with basin modeling to define the Sirte shale petroleum generation and expulsion history, petroleum phase-type and quantity, and expulsion efficiency. Results indicate that the current maturation levels in the general range of 0.4–1.35 %VRo (equivalent to 405 ◦C–460 ◦C pyrolysis Tmax) that found to allow Sirte shale Formation to enter transformation levels ranging from 20% to 91%, which is equivalent to 1,615 m–3,627 m burial depth. Sirte shale Formation is dominated by two types of organofacies (B and D/E), which are characterized by %TOC up to 5% and hydrogen index from 400 to 700 mg HC/g TOC with sudden lateral and vertical variation due to the influence of the marine and transitional – terrestrial sedimentary environments. Similar indications from the biomarker data were Pr/Py ratio shows a significant existence of anoxic and dysoxic environments (generally, 0.4–2.4). Alga marine (dominant), mixed, and minor terrestrial organic matter was defined to dominate the Sirte shale Formation as indicated by Pr/nc-17 and Py-nc18 data. The petroleum generation history of the Sirte shale Formation occurred in the Oligocene time (~30 Ma). The higher expulsion efficiency for the oil phase, up to 84% detected in the deeper parts of the basin, and lower gas expulsion efficiency with its maximum up to 63%. During the geological time, two primary petroleum phases were generated and expelled (oil and gas) from the Sirte shale. The bulk fluid properties generated from Sirte Shale Formation indicate that range of GOR from 400 to 2000 scf/bbl and API in the range of 30–60.
Rajab El Zaroug(8-2022)

Petrophysical characterization og Garia Formation, Lower Eocene, at Bahr Essalam Field, offshore Basai, NW Libya

Abstract offshore Basin represents one of the most important basins in Libya, It covers are an area a large part of the Tripoli-Gabes Basin , and a contains main structures as " B " which know Bouri Filed and ‘Bahr Essalam’ area ( NC41 ) is known as " C "structure and located in the Northwestern offshore Libya. The Metlaoui group (El-Garia Formation ) is main reservoir ( Lower Eocene age) in Bahr Essalam Field , consists of Nummulites limestone and tidal dolomites witnessing a regressive pulse in the basin evolution Limestone with average thickness more than 500 feet. The main purpose of this study is to evaluate and investigated the petrophysical characteristics of El-Garia Formation in Field , Bahr Essalam Field through the analysis of well log data available for five wells distributed in Concession NC41. The well logs signature indicate, the limestone is main lithology. With 16-22% Average porosity and 9.1% average water saturation with 198 ft average net pay . In this study the repeat formation test was used for delineate type of hydrocarbon ,the result indication the gas represent the main type of fluid . Keywords:, El-Garia Formation, Metlaoui Group, Lower Eocene, at Bahr Essalam Field, offshore Basin , NW Libya
Rajab ElZaroug, (3-2022)
عرض

Lithology Investigation of Shaly Sand Reservoir by using Wire Line Data," Nubian Sandstone" SE Sirt Basin

dentify the rock lithology has important meaning for estimating the reserve of petroleum as reservoir capacity and storage ability. The lithology identification from well log based on not conventional cross plot proposed and studied, which is more easier instead of rock core data observation results. However, this work carried out comparison between chart and analytical solution of matrix parameter (ρma and ΔTma) estimation values of producer shaly sand reservoir, and present the main depositional environment affects. In addition to influences of pyrite, ferruginous encrustations, organic material throughout this studied reservoir. Consequently, variety of matrix parameters values is contributed by clay minerals present in this reservoir type. This study based on wire line data measured over than 750 feet produced Upper Nubian Sandstone belong to two oil fields, SE Sirt Basin. This shaly reservoir divided into three main units (R, E and F), and each unit has been subdivided into three subunits (F3, F2, F1, E3, E2, E1, R3, R2 and R1) from bottom to top according to depositional and petrophysical properties.
Bahia Muftah Ben Ghawar(12-2016)
موقع المنشور

Origin and Depositional Environments of Abu Shaybah Formation, Ghanimah Area, NW of Libya

Abstract

Abu-Shaybah Formation is located on the coastal of the Meditrranean sea South of Ghanimah North West of Libya, between Tripoli and Al Khumes, about 100 km East of Tripoli. It lies on the eastern end of Jabel Nafusa flank. Abu Shaybah Formation Ghanimah area of Late Triasic age, consists of sandstone. The sedimentary structure in the lower most part from studied outcrops reflect NW paleocurrent direction indicating that Jabel Nafusa uplift poorly effect the study area. The upper part of studied succession changing in pallaeocurrent dirction to NE due to Jabel Nafusa uplifting. The extreme changing of paleocurrent direction and paleoslope direction to East due to continuous increase in Jabel Nafusa uplift, direction of vertical joints in Wadi Qirrim presented from NW to SE dirction. The rocks of Abu Shaybah Formation analyzed using differnt kinds of technique, Polrized Microscpe, XRF, SEM techniques. The study of sedimentary texture (grain size, roundness, sorting, and sphiricity) and sedimentary structures showed that Abu Shaybah Formation outcrops deposited in response to two fining upword cycles, formed mainly in Braided Stream Rivers with some effects of meandering. The sequences of Abu Shaybah Formation outcrops that exposed in Wadi Qirrim have been identified on many types of sedimentary facies associated with given sedimentary stucture as, Planar cross bedding, Convolute bedding, Trouph cross bedding, Ripple bedding, Shrinkage cracks, Plant rootlets, Concretions, Unconformity, Channels, Massive bedding, Laminated bedding, and the results which located on the grain size of quartz also loacted on the grain size of heavy minerals like tormaline, zircon and reutile.
سليم معمر قجوم (2009)

Approximations of Geomechanical Parameters and In-Situ Testing From Standard Penetration Test Results Correlation Study

Abstract

Measurements of in-situ data for geomechanical parameters are very essential part of geotechnical engineering design, but the time and the budgets are major issues, The design engineer must make critical decisions at several steps throughout the design stages to obtain the most reliable and realistic soil and rock property information. Because of that, the empirical equations are increased in use during the early stages of engineering design work. In any geotechnical investigations, most probably, will be involved in using Standard Penetration Test (SPT). It is a very popular test among geotechnical engineers. Therefore, it will be economically very useful if the results of SPT as N-values could be used to calculate the other geomechanical parameters. The sites of investigation are the Zawia Combined Cycle Power Plant, West Mountain Power Plant at Rowies, Tripoli and Tunisa. The data were collected from 13 boreholes, and more than 160 points. Which gave wide reliable results. Field investigations include Cross-Hole, Down-Hole seismic techniques, Standard Penetration Test SPT, Cone Penetration Test CPT and pressuremeter test PMT. The variation of seismic waves velocity (Vs & Vp) and dynamic modulus (shear modulus, young modulus, and bulk modulus) of sand and weak rock were studied and some correlations were developed. Also the effects of depth on the correlations were investigated. The correlations compared with previous relationships. The results showed that the power function provides the best fit for correlation between seismic wave’s velocity and dynamic modulus data with SPT N-value. The correlation coefficient (r) range 0.77-0.54 for sand and for weak rock. Range is 0.82-0.58. The multiple power regression analysis enhanced the correlation coefficient of sand and weak rock to ranges 0.82-0.58 and 0.97-0.92 respectively. These results are higher than the previous results. A single value of geotechnical parameters is very difficult to determine because the properties of material vary from point to point in the way that, it depends on a set of conditions so geotechnical parameters (seismic waves velocity and dynamic modulus) were determined between an upper and lower limits. The results of statistical analysis of relationship between SPT N-value and Cone Penetration Test (tip resistance qc) for all available data show that a linear regression with zero intercept as best fit correlation. of r=0.77. This result is equivalent to previous work. The logarithmic regression gave the best fit for the correlation analysis between the pressuremeter modulus EPMT and N value by r=0.81. The relationship between the limit pressure PL and N value was shown that, the linear regression was the best fit. The best-fit regression indicated a logarithmic relationship between the pressuremeter modulus (EPMT) and limit pressure (PL), with r=0.81 and 0.66 respectively.
ملاك عبد اللطيف ابوعرقوب (2010)

Classification, Enhancement And Stability Of Backfill And Embankment Case Study: Tajoura – Misurata

Abstract

Normally the study and investigated of earth material from the view of their uses as embankment and backfill material has a great importance in earth woks. This research concerns the assessment of earth masses and their properties which related embankment and backfill suitability as well as providing a mixing methods to upgrade the unsuitable within the accepted standards. The objectives of this research could be briefed by the investigation of earth masses along the study area which is governed by the distribution of superficial deposits comprehensive laboratory testing of soil samples molding Andes properties classification testing proctor and California bearing ratio recognition of suit able and non suit able backfill soil enhancement of unsuitable soil by mixing with other suitable soil such as quarry dust provided by nearby quarry correlation analysis and economic feasibility the study area is located in east of Tripoli from Tajoura to Misurata . This study manly concluded that as long as the poorly graded soil (A3) is difficult to be compacted according to the engineering properties of such soil are enhanced certainly by mixing with good sailable materials such as quarry dust. This research also conduced that the compaction properties will be enhanced by mixing where the optimum moister content is needed at the increase of maximum dry density. This research provides procedure of mixing design and recommendations for the mixing to achieve better results.
عبد السلام محمد بحرون (2011)

Petrophysical Study of the Nubian Sandstones in Concession 59D, E. Sirt Basin, Libya

Abstract

The Nubian Sandstone Formation is a significant hydrocarbon reservoir in the Concession 59D, Eastern Sirt Basin, Libya. This formation is underlain uncomfortably by granitic basement and/or by the Hercynian unconformity and overlain uncomfortably by Pre-Upper Cretaceous followed by an Early Upper Cretaceous Transition beds. The Nubian formation is a thick sequence comprises mainly of sandstone, siltstone and shale.The Nubian Formation in this area has been subdivided into three stratigraphic members; namely Lower Sandstone, Middle Shale and Upper Sandstone (main reservoir well be focus of this study).The Upper Sandstone is the upper most subdivision of the Nubian Sandstone sequence consists mainly of white, grey to brown sandstones, ranging from fine to medium, locally coarse grained, moderately cemented with straight to concavo convex or slightly sutured grain contacts. This reservoir is a complex of fluvial sands deposited in Braided and Meandering streams.The reservoir fluids are very rich retrograde condensate gas and waxy oil with pressure at slightly above the saturation pressure. Most of this hydrocarbon in this reservoir has been sourced from the Nubian Middle Shale Member, but the Upper Cretaceous shale and Evaporates belonging to the Transition beds sequence have a significant potential source. The trapping mechanism in the field is a combined structural and stratigraphic trap for the Nubian Sandstone with the southern closure against the tight Nubian facies and basement of the Gialo High. Reservoir properties across the North Gialo Study Area vary in terms of porosity, permeability fluid saturation. These variations are indicated through the porosity, permeability and saturation maps and charts based on well log analysis and lab core sample measurements. These properties are discussed in the reservoir characterization part of this thesis.
عواطف عبد الله بودربالة (2012)