bluuebunny/crossref_metadata_2025_split huggingface dataset:
Tectonic Criteria of Oil and GAS Potential at the Transitional Part of the Susha-sea Along the Western Coast of the South Caspian Depression
Authors: Aslanov Baylar , Jabizade Nurlan , Khuduzadeh Arastun , Aslanzade Fidan 
Published: October 2021

Abstract
The southern part of the South Caspian oil and gas Basin (SCB) is one of the main oil and gas producing regions in the central part of Eurasian continent. The large number of offshore oil and gas fields is located here, therefore the basin considered as a promising direction for the further perspective zones survey.
The basin is located between the uneven-aged mountain structures of the Lesser and Greater Caucasus in the west, the Great Balkhan and Kopet-Dag in the east, the Talish and Elbrus ridges in the south. In the north, it is limited by a sub-latitudinal regional deep fault, which fixes the northern slope of the complex Absheron-Balkhan zone of uplifts, which is part of the South Kura and Western Turkmenistan depressions. Among the structural elements of the second order, the South Absheron depression, the complex Abikh swell and the Javadkhan-Natevan zone in the west should be noted; Turkmen terrace, Ogurchinskaya step and Chikishlyar-Fersmanovskaya-Weber-Western zone in the east (Fig. 1).
The central place in the structure of the basin is occupied by the South Caspian Mega Depression (SCMD), in the most submerged part of which - the pre Elbrus Basin - the basement lies at a depth of about 25 km, and the sedimentary stratum, including Mesozoic, Cenozoic and Quaternary formations, is largely represented by the Pliocene - post-Pliocene sediments, reaching a total thickness of 8–10 km and more in the troughs (Fig. 2, 3).
Organic Geochemical Characteristics of Core Samples from Central Primorsk-Emba Province, Precaspian Basin, Kazakhstan
Authors: Jarassova Tolganay , Altunsoy Mehmet 
Published: October 2021

Abstract
The Primorsk-Emba province is one of the main oil and gas region of the Precaspian basin. The resources of the Primorsk-Emba oil and gas region range from 5 to 12 billion tons of oil and from 2 to 6 trillion m³ of natural gas. This study primarily concentrates on investigating the organic geochemistry and petroleum geology characteristics of sedimentary units that generated oil in the central Primorsk-Emba province. 20 core samples taken from the Jurassic units in the western part of the study area are characterized by organic matter amount, hydrocarbon production potential, type of organic matter, maturity of organic matter. According to the Rock-Eval results Jurassic aged rocks generally have a petroleum potential ranging from weak to excellent, the organic matter is between Type II (oil prone), Type II-III (gas-oil prone) and Type III (gas prone), and the degree of maturation is immature-mature stage. Oil extracts were characterized by geochemical methods including Gas Chromatography (GC) and Gas Chromatography–Mass Spectrometry (GC–MS). n-alkanes and isoprenoids were evaluated by High-Resolution Gas Chromatography (GC-HR), aromatic hydrocarbons were evaluated by Low Thermal Mass Gas Chromatography (GC-LTM), terpanes (hopanes), steranes / diasteranes and aromatic hydrocarbons were evaluated by Gas Chromatography-Mass Spectrometry (GC-MS). The GC and GC-MS data obtained, it has been determined whether the paleoenvironment characteristics of the study area, hydrocarbon potential, type of kerogen, maturity level of organic matter and whether it is affected by biodegradation. Distribution of n-alkanes in the GC showed that no biodegradation was observed in analyzed samples, source rock deposited in a marine environment under reducing conditions and an organic matter that occurred were generated by marine carbonates. Based on maturity parameters, studied oils are mature and located on the oil generation window. According to biomarker age parameters C28 / C29 and norcholestane (NCR)/nordiacholestane (NDR) samples are generally Mesozoic (Triassic-Jurassic- Cretaceous) origin, nevertheless there are also levels corresponding to the Paleozoic (Permian) late stages.
Influence of Secondary Alterations on the Structure of the Pore Space of the Upper Permian Carbonate Deposits of the Northern Side Zone of the Caspian Basin
Authors: Ayupov Amir Rustamovich , Khafizov Sergey Faizovich , Iskaziev Kurmangazy Orinbgazievich 
Published: October 2021

Abstract
The analysis of the facies distribution of reservoirs within the Moscow-Artinskian sedimentation rim within the Northern part of the Pre-Caspian Basin was carried out.
The Teplovsko-Tokarevskaya group of deposits is a chain of carbonate structures stretched in the sub-latitudinal direction. They are consist mainly of bioherm structures, which include tubifytes, foraminifera, crinoidea, ostracods, ostracods, etc.
From the lithological point of view, the reservoir rocks are represented by dolomite-limestone differences-from organic limestones to secondary chemogenic dolomites. The influence of facies distribution and secondary dolomitization on the structure of the pore space remains controversial and requires detailed study.
The concepts of secondary dolomitization were analyzed and one of the concepts of the formation of secondary dolomites and anhydrites was used to justify the facies distribution: Zones of secondary transformation (dolomitization) form a sweet spots zone in the Artinskian carbonate horizon when high-salinity (Mg2+) waters from the Filippovsky horizon carbonates are infiltrates to Artinskian carbonate. As a result of the discharge of elision waters during digenetic dehydration of gypsum. After the anhydride overlaying of the Artinskian carbonate structure, several regressive-transgressive cycles occurred, which formed a sequence of consistent dolomite-limestone and gypsum layers in the Filippovskian time. During the diagenesis water contained in the gypsum was dehydrated into the permeable zones in carbonates of the Filippovsky horizon, followed by unloading in the region of the Artinskian horizon.
Evaporite sedimentation of chemogenic carbonates and gypsum created a condition for the subsequent infiltration of sulphate and magnesium waters in the direction dip formation angle. The source of magnesium is the water remaining after the precipitation of gypsum and carbonates in the Filippovskian time.
Changing Patterns of Learning in Oil and Gas Industry
Authors: Hajiaghabayli Ferid , Babayeva Elnara , Haydarov Mehman 
Published: October 2021

Abstract
Covid-19 pandemics have made innovations even more crucial and used them to take market power over competitors considering challenges that the world and global economy face. To achieve this goal, organizations need competent and high-expertise human capital as a workforce. That is one of the key reasons organizations increase their investment in developing, re-skilling and up-skilling their workforce via various learning and development programs and solutions compared to previous years.
Given the direct impact of this process on the company's revenues, the following graph demonstrates the value flow generated (Figure 1):
Organizations aim to ensure minimum time and efficient expenditure structures to achieve and build a learning system that delivers sustainable developmental solutions and interventions. Knowledge sustainability is a purpose, which focuses on various learning methods and solutions to make knowledge last and kept longer.
A learning management system (shortly, LMS) is a platform that gathers all the learning solutions in one place and automates the process of learning to present development opportunities to end-users - learners/employees. Digital learning enables users/employees to develop their competencies quickly, no matter the place and time and makes knowledge and information accessible for all, and gives an unlimited option to relearn, repeat and refresh anything already completed unlimitedly.
The UNFC Concept and the Possibility of its Application in Azerbaijan
Authors: Garayeva Narmina , Zeynalov Gasham , Ahmadov Elkhan , Hajiyev Agarza , Rahimov Farid , Aslanova Aida 
Published: October 2021

Abstract
Moving towards sustainable development, Azerbaijan joining SDG Agenda 2030 adheres to the policy of developing both hydrocarbon and non-hydrocarbon resources for economic diversification. At the same time, efficient resource management becomes a vital process at the governmental and transnational companies’ levels. Therefore, a competent classification and structuring of all reserves and resources will be inevitable soon to improve their accurate estimates and effective management in various aspects, including resource availability, technical feasibility, and environmental-socio-economic viability. The importance of the latter is indisputable since social and environmental stability is an essential component of the country's sustainable economic development policy.
From this perspective, the United Nations Framework Classification for Resources (UNFC) is seen as a tool to help accomplish these tasks and provide simple screening and verification procedures for evaluating future investment projects.
Given that hydrocarbon reserves make a significant contribution to the economy, a study on the application and adaptation of UNFC to local petroleum resource management has been granted as a pilot project to assess the feasibility of its further implementation for other energy and mineral reserves and resources of the country. The UNFC current state analysis as a global standard for classifying energy and mineral resources and their applications is carried out to launch the project. The review covers various case studies, including the classification of hydrocarbon reserves and resources (HCRR) using UNFC (Mexico project, transition projects to the classification of the Russian Federation, etc.), as well as mineral resources in different countries.
The research primary goal is to screen different approaches and techniques to assess the practicality of their application to petroleum reserves and resources of Azerbaijan in transferring currently used old Former Soviet Union HCRR classification to UNFC, possibly via PRMS. In addition, a Case Study Research based on the Field A data in Azerbaijan is conducted.
Designing the Thermal Enhanced Oil Recovery as a Key Technology of High Viscosity Oil Production
Authors: Shaken Mukhtar Shakenuly , Zhiyengaliyev Baurzhan Yerikovich , Mardanov Altynbek Suleymenuly , Dauletov Adil Sultangaliyevich 
Published: October 2021

Abstract
Due to the decrease in "easy" oil reserves, oil companies are focusing on "hard-to-recover" reserves, in particular, high-viscosity oil reservoirs. Shallow oil reservoirs are mainly concentrated in the Cretaceous horizons, in the western region of the country, along the Caspian coast. One of them is a high-viscosity oil reservoir, consisting of three Cretaceous horizons. The average viscosity of oil in reservoir conditions is around 746.7 cP. The current achieved oil production is only 5% of the initial recoverable reserves, and designed oil recovery factor is 38% and implies the full-scale application of thermal methods of EOR.
The objective of this work was to choose the most suitable thermal method of EOR and to assess the prospects of applicability with the calculation of economic feasibility. Considering the geological features of the reservoir, the cyclic steam stimulation was chosen as the optimal method to increase oil recovery. In order to assess the expediency of this technology, was initiated project on thermal modeling the technology based on the current geological and hydrodynamic model of the field, using the results of laboratory studies, calculations were performed on imagined horizontal wells, and carried out the analysis of technical and economic efficiency.
According to the results of calculations on the hydrodynamic model, the production rates using the technology of cyclic steam stimulation in horizontal wells are 30% higher than the production rates of "cold production", and the difference in accumulated oil production over 5 years will be 20–30%.
Application of Hybrid Biosystems for Stimulation of Oil Production
Authors: Suleimanov Baghir Alakbar , Rzayeva Sabina Jahangir , Akhmedova Ulviyya Tahir 
Published: October 2021

Abstract
Microbial enhanced oil recovery is considered to be one of the most promising methods of stimulating formation, contributing to a higher level of oil production from long-term fields. The injection of bioreagents into a reservoir results in the creation of oil-dicing agents along with significant amount of gases, mainly carbon dioxide. In early, the authors failed to study the preparation of self-gasified biosystems and the implementation of the subcritical region (SR) under reservoir conditions.
Gasified systems in the subcritical phase have better oil-displacing properties than non-gasified systems. The slippage effect determines the behavior of gas–liquid systems in the SR under reservoir conditions. Slippage occurs more easily when the pore channel has a smaller average radius. Therefore, in a heterogeneous porous medium, the filtration profile of gasified liquids in the SR should be more uniform than for a degassed liquid.
The theoretical and practical foundations for the preparation of single-phase self-gasified biosystems and the implementation of the SR under reservoir conditions have been developedSR under reservoir conditions. Based on experimental studies, the superior efficiency of oil displacement by gasified biosystems compared with degassed ones has been demonstrated. The possibility of efficient use of gasified hybrid biopolymer systems has been shown.
Concentric Coiled Tubing, Proven Sand Cleanout Technology for Sub-Hydrostatic Wells in Caspian Sea
Authors: Hasanov Emil , Mammadov Hajagha , Correa Pedro 
Published: October 2021

Abstract
Influx of sand production is one of the major issues faced in oil and gas wells on the Caspian region. Although there are multiple technologies to address this issue, the application of these technologies require the well to be cleaned before proceeding with any kind of remedial application. Concentric Coiled Tubing (CCT) sand vacuuming technology has brought a massive advantage for efficiently cleaning the wellbore of sub-hydrostatic wells in Caspian Sea.
CCT system is the Coiled tubing string inside of Coiled tubing string which essentially provides a smaller second annular return route for the wellbore solids while simultaneously boosting the return pressure and allowing to clean the sand where the bottomhole pressure (BHP) is low and not enough to support the circulation of fluids used for the cleanout. Cleanout fluid is pumped through the inner string to power the downhole jet pump comprised in CCT bottomhole assembly (BHA) which creates a drawdown that vacuums the solids and circulates the solids back to surface via the CCT annulus.
The solid performance of the CCT system has an established track record worldwide and application of this sand cleanout technology brought a solution for recovering many wells with low BHP and has been successfully implemented since 2013, providing a method for cleaning out tons of accumulated sand particles from challenging wells in Caspian Region. With the complex system being used for cleaning out sand and also surface handling of the solids in the return flow from the wellbore, CCT sand vacuuming technology has proven to be effectively functioning in all cases that it was selected for so far.
This Paper reviews the design and mechanism of the CCT sand/well vacuuming system as well as the results of several well intervention cases with its successful execution and lessons learned in Caspian region.
Field-Proven Well Surveillance Techniques Designed for an Early Well Scaling Diagnosis and Timely Well Performance Reinstatement: Case Study from the Kashagan Field
Authors: Kauzhanova Aktoty , Te Lyudmila , Reedy John , Ehighebolo Thaddeus Ivbade , Heinerth Mirko Bastiaan , Khaidarov Yerbol 
Published: October 2021

Abstract
Some wells in the Kashagan field did not perform as well as expected. Despite producing virtually no water, calcite deposition was found to be the root cause of the problem. A comprehensive well surveillance program, which was proven to be very efficient for an early scaling diagnosis, was developed by the operator, North Caspian Operating Company (hereafter NCOC). As a result, well scaling is currently well managed and prevented from reoccurring. The objective of this paper is to share an early experience with well scaling in the Kashagan field, as well as to describe the developed set of well surveillance techniques.
The aim of the various well surveillance techniques discussed in this paper is to improve an Operator's ability to identify the very first signs of scale accumulation. This, in its turn, enables to introduce timely adjustments to the well operating envelope and to schedule a scale remediation / inhibition treatment with the intention to prevent any potential scaling initiation from further development. The approach is quite extensive and incorporates continuous BHP/BHT monitoring, routine well testing, PTA analysis, and fluid/water sampling.
Developed approach experienced multiple revisions and modifications. Further optimization continues, however, the described well surveillance techniques represent the latest Operator's vision on the most efficient way for well scaling monitoring and identification. In the Kashagan field, BHP/BHT readings have proved to be the most direct and instantaneous indication of any early signs of potential deterioration in well performance (qualitative analysis) while well testing and PTAs are considered as the most essential techniques in confirming and quantifying scaling severity (quantitative analysis). It is important to mention that BHT increase is explained by Joule-Thomson heating effect being specific for the Kashagan fluid (happening during increased pressure drawdown). This, in turns, enables to predict future well performance, design well operating envelop accordingly and, most importantly, develop a yearly schedule for proactive well treatments with SI.
In conclusion, it shall be highlighted that discussed complex of well surveillance techniques has been concluded to be very efficient and reliable tool in identifying any scaling tendencies at its initial stage. Due to successful implementation of this approach in the Kashagan field, scale development is now well-managed and kept under control. To mention, that utilization of well surveillance techniques and methods outlined in this paper may reduce the time required to identify and ultimately mitigate well scale accumulation in any active assets with similar operating environments.
Uncertainty and Risk Assessment Using Ensemble Modeling for Major Development Decision
Authors: Asgarov Murad , Arslan Ozan , Salim-Zade Fidan , Aliyev Aghamehdi , Abdullayev Turan , Sadikhov Farhad 
Published: October 2021

Abstract
This paper summarizes a risk framing and assessment exercise to support a major development decision in Azeri-Chirag-Gunashli field located in Azerbaijani sector of Caspian Sea, using at scale implementation of ensemble modelling technique.
A multi-disciplinary team identified a comprehensive list of geological and mechanical uncertainties and their inter-dependencies that could impact the project outcome. 20000 subsurface scenarios with unique uncertainty parameter combinations, based on Monte Carlo approach, were modeled using reservoir simulation software. Match quality to the actual performance helped to select an ensemble of unique subsurface scenarios. With the non-subsurface uncertainties in the predictive stage, the ensemble was used to inform the investment case's incremental value range.
The ensemble predicted a cloud of outcomes around the reference case with -25% and +12% uncertainty range. This cloud assumed the same (reference case) sequence and location of the wells. The team selected distinct scenarios from the cloud to communicate the risks on key project metrics. Incremental recovery and production ramp-up variation against significant uncertainties guided the selection of distinct downside and upside scenarios for economic evaluation to ensure the robustness of development decision.
The initial cloud was considered to be unmanaged as the well locations were exposed to reservoir property, connectivity, sweep, and other uncertainties for a specific scenario in the ensemble. The team recognized the long duration of development activities and tangible subsurface learning opportunities from drilling through multiple reservoirs and other surveillances, particularly on the key uncertainties ("heavy hitters"). This observation was leveraged to manage uncertainties and make appropriate well location and sequence decisions. Overall uncertainty range slightly narrowed down to -20 % and +16 % while providing an appropriate downside and upside profiles for the investment case.
Assessing the impact of key uncertainties on investment value helped refining surveillance and risk management plan with focus areas on well and facility design to ensure risk management measures are executable.
Frictional Contact Problem of One Dimensional Hexagonal Piezoelectric Quasicrystals Layer
Authors: Huang RuKai , Ding Sheng hu , Zhang Xin , Li Xing 
Published: October 2021

Abstract
Based on three-dimensional (3D) general solutions for one-dimensional (1D) hexagonal piezoelectric quasicrystals (PEQCs), this paper studied the frictional contact problem of 1D-hexagonal PEQCs layer. The frequency response functions (FRFs) for 1D-hexagonal PEQCs layer are analytically derived by applying double Fourier integral transforms to the general solutions and boundary conditions, which are consequently converted to the corresponding influence coefficients (ICs). The conjugate gradient method (CGM) is used to obtain the unknown pressure distribution, while the discrete convolution-fast Fourier transform technique (DC-FFT) is applied to calculate the displacements and stresses of phonon and phason, electric potentials and electric displacements. Numerical results are given to reveal the influences of material parameters and loading conditions on the contact behavior. The obtained 3D contact solutions are not only helpful further analysis and understanding of the coupling characteristics of phonon, phason and electric field, but also provide a reference basis for experimental analysis and material development.