bluuebunny/crossref_metadata_2025_split huggingface dataset:
The Development and Implementation of Subsoil Use Standards for the Petroleum Sector in Kazakhstan
Authors: Harrison Bob , Kairbayev Nurzhan 
Published: October 2018

Abstract
Modernization of the regulatory framework of the Republic of Kazakhstan (RoK) will complement the "100 Concrete Steps" national initiative of President Nazarbayev. Planned reforms aim to increase the transparency and predictability of the subsoil use sector by implementing an international system of reporting standards. The Society of Petroleum Engineer's Petroleum Resource Management System (SPE-PRMS-2007) is the most likely choice for the hydrocarbon sector, as the guidelines can be altered to meet the needs of RoK to increase the contribution of petroleum production to drive economic growth, improve governance, and attract more investment, along with best available practices and technologies, in RoK.
A comparative analysis of the leading petroleum resource reporting systems used by governments and stock markets around the world concurred that a tailored SPE-PRMS-2007, which was named KAZ-PRMS, was the most appropriate system for the needs of RoK. Discussions were then held with a RoK Working Group, which was comprised of government bodies, technical institutes and operators, to address their concerns and to get their ‘buy-in’ to create a road map for the development and implementation of the new Code for Reporting Hydrocarbon Resources (Code) as required by international SPE-PRMS standards.
The initial concerns about migrating to a new reporting system of some of the Working Group were overcome via open and lively discussions, by workshops and through focused training sessions. The various parties concurred that migrating to KAZ-PRMS could be a valid alternative to the existing RoK resource reporting system from the Soviet era, which is disliked by the international investor community. There remained some concern over the proposed speed of change presented in the road map, but there was consensus for the need for change.
The administrative, technical and cultural challenges facing the RoK, which intends to radically overhaul its Soviet-era regulatory system and its petroleum resource reporting structure, whilst remaining legally compliant, are described in detail.
Regulatory Compliance in Oil & Gas Industry of Kazakhstan
Authors: Seitimov Talgat 
Published: October 2018

Abstract
An objective of current paper is to provide a brief explanation and guidance on local regulatory requirements applicable to oil and gas projects in Republic of Kazakhstan (hereafter - RoK or Kazakhstan).
The scope of this paper comprises the following:
An essential information about the Regulatory Compliance in Kazakhstan Main regulatory requirements during the project development Useful notes in respect to regulatory compliance Main peculiarities of RoK regulations
It is not an intention of this paper to detail each regulatory aspect and requirement; rather, the intent is to define the main important aspects and provide the clear vision on regulatory compliance to oil & gas companies working in Kazakhstan.
Marketing, tax and labour regulatory requirements are not considered in current paper at all.
Wells’ Water Cut Measurements with Limitations of Testing Facilities in the Field
Authors: Shektebayeva Raziya , Bissakayev Beibit , Iraliyev Amangali , Mardanov Almas , Karatayev Kanat , Saada Tamer , Madeley Benjamin , Brancolini Alberto , Di Federico Emanuele Giustino 
Published: October 2018

Abstract
The objective of this article is to demonstrate recent results of a water cut measurement campaign in the Karachaganak oil and gas condensate field. Historical, inaccurate well water cut assessment was due to the limitations of well test facilities which led to uncertainty in short- and long-term production forecasts. Several approaches were conducted to eliminate uncertainties in water cut measurements and to evaluate and define adequate tools to use for future water cut analysis.
The use of a mobile sampling flow loop installed at the well head, where turbulent multiphase flow is guaranteed, was a safe and reliable approach to measure the water cut of the producing low and high productivity wells. Sampling and analyzing the fluid at the well site at various operating well head pressures, frequently and for long periods of time, resulted in better understanding of water cut dependence with changes in drawdown. In addition to the use of sampling on site, the optical sensor (OS) technology was a trial tested on two wells along with the sampling flow loop to confirm the accuracy of the technology.
The existing test separators were not designed to handle high water rates; moreover, due to the complexity of the produced hydrocarbon, multiphase flowmeters are not able to accurately measure the correct fluid phase contribution and, as a result, inaccurately estimate phase rates.
The OS tool demonstrated accurate real-time water cut readings in the liquid phase, when compared with the flow loop samples, as long as a turbulent flow is guaranteed during measurement. Thus, this technology can be considered as an accurate tool for water cut measurements. The possibility of temporary and permanent installation of the optical sensor tool at the well site or test lines is under evaluation.
The current field development focuses on improved recovery from the oil rim which is above a weak aquifer. In the historically developed areas of the field this aquifer is separated from the hydrocarbons by impermeable shale and therefore water production has been minimal. Current and future development requires the drilling of new wells in areas not protected by barriers; this has led to a number of recent wells having a relatively early water breakthrough.
As a result of accurate water cut measurements, unallocated water in the field was well defined and led to better control of water producing wells to maintain stability of process facilities. This application confirmed the limitations and low level of accuracy of the existing well test separators.
The successful campaign to improve water cut assessment was critical to update and re-evaluate production wells’ operating philosophy, reservoir management, and the future development strategy of the carbonate reservoir.
Analysis of Depositional Environment within Karaton-Tengiz Uplift Zone in Southeastern Part of the Pre-Caspian Basin
Authors: Yeskozha Bazar , Aimagambetov Marat , Ismagulova Saltanat 
Published: October 2018

Abstract
The present paper describes the results of analysis of depositional environment and tectonic setting within Karaton-Tengiz uplift zone in the southeastern part of the Pre-Caspian basin. The main purpose of the study is generalization and interpretation of geological and geophysical data for creation of stratigraphic charts and a description of lithological and tectonic processes for reconstruction of the structural history of pre-salt prospective traps located close to Tengiz field.
It is known that carbonates are "born, not made"; hence, their characteristics can give an insight into their depositional environment. The combination of such factors as availability of the light, warm climate, chemical composition and transparency of the water define the growth of the reef-building organisms. The highest carbonate production takes place close to the water surface; therefore, facies and texture of carbonates may be linked to the sea level changes. This means that understanding of the depositional environment and sequence stratigraphy may be used for a potential reservoir description where no well data is available. As a general understanding of the relative sea level fluctuations and its effect on carbonate growth, comparison of vertical thickness of studied platforms was carried out.
Analysis of regional seismic reflectors P3 (Top of Middle Devonian, tentative), P2D (Top of Upper Devonian), P2 (Top of Carboniferous), P1 (Top of Permian), VI (Kungurian salt deposits), V (surface of unconformity, Triassic), III (Top of Jurassic), II (Top of Lower Cretaceous) was also carried out for understanding of tectonic processes. Dipping of reflectors, thickness and depth variation of time-equivalent units, unconformities may indicate the change in tectonic setting. The shallowest depth of top of carbonates is observed on Tazhigali-Pustynnaya structure, gradually deepening towards Ansagan and Maksat to the south-southeast. Also, post-salt III and V reflective horizons are inclined from the north to the south of Karaton-Tengiz uplift zone.
Tectonic deepening in the south-southeast direction took place in several stages. The first stage, most probably, took place in Late Devonian–Early Carboniferous, as the result of which Ansagan and Maksat structures drowned. In the northern part of the Karaton-Tengiz uplift, the growth of reefs continued up to Late Carboniferous.
Well logging interpretation and published papers were integrated when possible. As the result, a conceptual model of the geological history and stratigraphic charts were created for the studied region.
Evaluation of In-Situ Combustion Efficiency in Karazhanbas Oilfield, Western Kazakhstan
Authors: Abishev Aziz , Tokarev Vitaliy , Sagyndikov Marat 
Published: October 2018

Abstract
Among various processes of EOR, in-situ combustion (ISC) received an increased attention in the world. Such specific features as applying to deep reservoirs and at any stages of depletion, lack of transport heat losses, cheap working agent (air) makes this method most thermally efficient and economically comparable to steamflooding.
The Karazhanbas experience of ISC implementation is a bright example of well-designed project. After the estimation of reserves in 1978 there were created two large fields to develop thermal EOR methods. They are the VVG field to develop in-situ combustion and the PTV field to develop the steam flooding. Unfortunately, this project was not fully completed and was interrupted before the planned deadline because of the current economic situation in the country in the 90s. Anyway the project demonstrated high technological and economic efficiency.
The study (article) describes a history of project, results of logging data, problems encountered during combustion process and comparative analysis of developed and existing methods.
Standout Concept of Well Clean-up and Testing—Secures Long-term Sustainable Evolution of the Field
Authors: Dombayeva Anar , Viti Massimo , McGachy David , Thorn Nigel 
Published: October 2018

Abstract
The Karachaganak (KGK) field is situated within an environmentally sensitive location which includes a conservation area containing lakes, woodland and abundant wildlife. Additionally, surrounding the field there are several inhabited villages. As in other parts of the world, if well operations are not properly managed, there is the potential to directly impact this fragile environment, as a result of HC flaring with emissions containing both poisonous H2S and toxic SO2 during the well operations.
Despite applying best-in-class environmental drilling and completion practices in the well construction processes, there remained the challenge of how to reduce emissions resulting from well clean-up activities in the field, with the eventual goal of achieving zero emissions.
This paper outlines the transition of well clean-up and testing towards purely three phase "zero emission", broadly describing the evolution from conventional three phase flaring to a robust zero emissions approach.
The transition required new technologies to be implemented in stages which were all subject to; high level design reviews and rigorous HAZOP activities to, both define and guarantee the safe operational envelope at field implementation stage.
The result of this implementation are as follows: Maximizing oil recovery at highest value within optimal cost.Putting the newly drilled wells on production in advance and reviving suspended wells.Significantly reducing downtime.With to date a significant environmental impact reduction in the region of 95%.
The project anticipates deploying the last of the enabling technologies in the field in 4th Quarter 2018, which should see Karachaganak Petroleum Operating b.v. (KPO) achieve its long term aim of "zero emissions" during well clean-up phases.
Staged Acid Stimulation Initiative in Giant Carbonate Reservoir
Authors: Manakhayev Ruslan , Abilgaziyeva Nazgul , Bopiyev Chingiz , Saduakassov Bekzhan , Abdrazakov Dmitriy , Stepanov Vladimir , Se Yegor , Clarke John , Kamispaev Akylbek , Tyre Robert , Nurmanov Sagdi , Ismailov Bolat , Argynov Daniyar 
Published: October 2018

Abstract
Tengiz field is a super-giant carbonate reservoir located in the Western Kazakhstan. The carbonate matrix consists of almost pure calcite, which makes it very attractive for acid stimulation. Over the years matrix acid stimulation has been successfully used in Tengiz to remove near wellbore damage and enhance well productivity.
Despite successful production response from acid stimulation in the past, it was noticed from poststimulation surveillance analysis that tighter and less depleted intervals were often left untreated. This observation suggested that chemical diverting agents were not effective for long completion intervals and further opportunity for improvement was identified. In addition, existing two phase retarded acid had limitation due to high viscosity and had known issues during plant flowback.
New acid stimulation design has been proposed and successfully executed in three newly drilled wells. This acid treatment utilized staged stimulation concept, where diversion was ensured by mechanical isolation of lower intervals with inflatable packer. New single phase retarded acid system was introduced to address operational and plant processing challenges with two phase retarded acid. Core flow tests were performed prior stimulation to evaluate effectiveness of different acid systems. Results of core flow tests and wireline log data were used during simulations on new generation of matrix acidizing modeling software to determine parameters for optimal wormhole creation.
Proper planning and thorough technical assessment enabled execution of staged acid stimulation with new acid system incident free with less than 10% incremental cost in all three wells. Post-job surveillance program is in place to evaluate acid diversion and production contribution from tighter and less depleted intervals.
Utilization of Mobile Multiphase Flow Meter in an Uncertain H2S Media: Precautions and Benefits
Authors: Macary Sameh , Muhamadiyev Hasan , Mollaniyazov Eldar , Kaipov Yermek , Agayev Aydyn 
Published: October 2018

Abstract
The deployment of Multi-Phase Flow Meter (MPFM) from commissioning to execution campaign in harsh offshore/H2S uncertainty conditions is presented. The case study was performed in Lam and Zhdanov fields operated by Dragon Oil, Offshore Caspian-Turkmenistan. The objective was to enhance the quality of well testing and allocation factor by comparing test separators (TS) measurements against multiphase flow meter (MPFM) readings and, in a bigger scope to converge the difference versus onshore plant measurements of oil and water.
Commissioning stage of MPFM was started off by comparing its results with TS. Comparison program was made and followed by considering the operating envelope of both technologies: MFPM and TS, input PVT parameters, measurement conditions and success criteria. Water-liquid ratio (WLR) and water rate from MPFM was compared against wellhead samples utilizing automatic centrifuge and total water at plant.
MPFM was subjected to measure flow during both: well clean-up stage and production logging of a slugging well. High gas volume fraction and scale/wax precipitation have required methodology development to maintain the accuracy of MPFM.
14 wells were subjected to comparison test showing differences in gas and liquid rates between MPFM and TS are within acceptable criteria while difference in water rate was high due to slugging nature of flow. High-frequency measurements of WLR from MPFM showed water rates accompanying slugging were consistent with wellhead sampling and total onshore water production. Two-phase test separator was underestimating the water due to few sampling and improper separation at manual centrifuge.
In high gas volume fraction equal to 98.5% and above MPFM accuracy in liquid rate becomes very sensitive to reference point of gas. To maintain the liquid accuracy, the in-line measurement of gas point was done so that accuracy of liquid measurements improved.
MPFM has identified wells with scale and wax precipitation, which can be observed from photon counts deviation at two energy levels of gamma-ray spectrum. By adding 3rd energy level, it was possible to estimate the thickness of scale and wax on the wall of meter venturi throat and hence maintaining the MPFM flowing rate accuracy.
MPFM campaign showed accurate measurement of water for Cheleken in addition to adding efficient well testing frequency while providing reliable high data frequency. This case study shows the first mobile MPFM application in Caspian offshore for producing wells’ testing. Results in comparison with TS signifies better and faster ways to calibrate the surface TS. MPFM testing campaign has led to the early identification of possible flow assurance issues and consequently, development of methodologies and recommendations to ensure reliability of MPFM and permanent test separators.
Integrated Asset Modeling in West Siberia: A Case Study
Authors: Batalov D. A. , Yusupov R. Y. , Zykov M. A. , Zipir V. G. , Gontarev D. P. , Kukushkin V. , Bayguzov R. , Kraynova E. , Krivokorytova M. , Kharkovsky A. 
Published: October 2018

Abstract
As part of the LUKOIL smart-field project, the company develops and implements integrated modeling solutions in all its assets. LUKOIL-West Siberia, a subsidiary company that is LUKOIL's leading hydrocarbon producer, has chosen two pilot assets in Yamal to implement such technology solutions. This paper describes the creation and implementation of two integrated models, as well as model of gas transportation system from a group of fields located in the Yamal and the Krasnoyarsk region. Each integrated model includes the following components: reservoir – well – gathering system – processing. The results of the project implementation allowed to increase production performance and economic viability of the operator company and provided technology that enabled to forecast production rates with high accuracy.
The Key Development Geological Technology Research and Application of Heavy Oil Reservoir
Authors: Chen Zhong 
Published: October 2018

Abstract
This research is aimed at enhancing the oil recovery and re-development of heavy oilfield by development geology as the development of many heavy oilfieldsin the world hasentered middle-late stages at present. The development effect has become worse and worse gradually. So, it isan urgent thing to look for any effective alternative methods to sustain the stable production of oilfield.
This research formed four key technologies of development geology. The first is micro structure fine interpretation technology for theproblem aforementioned. Second, complex fault block oil reservoir prediction technology, including multi-attribute reservoir inversion prediction technology, tracking and prediction individual oil layer by combining well-log and seismic technology, confirming lateral continuity of sandstone bodies by seismic phase shifting technology. The third is favorable oil layer accurate evaluation technology, including favorable oil layer identification and tracking and depicting succession oil layer technology. The last is integration research of hard-to-recover reserve development and rolling exploration through conducting oil reservoir optimum selection.
This research further exploited the favorable oil accumulation zone by deepened integral structure analysis, realized new breakthrough of rolling and increasing reserve on account of intensifying the understanding of old field margin area, set up layer division development model of hard-to-recover reserve based on originating the idea of fine evaluation of individual oil layer and well-practicedthe integration applicationof the key technologies of development geology in the practice of the main developed heavy oilfield in Liaohe Basin. This research has greatly enhancedthe oil recovery factor of more than 10% to the first development andfinally realized the stable production of theoilfield.
This research established three innovative concepts, holistic research concept of oil development geology territory, individual oil layer fine evaluation concept and building the composite development concept allowing for the coexistence of multiple well types and varied development methods. It would have an important reference value to the continueddevelopment of heavy oilfield.
Antimicrobial Activity of Different Antimicrobial Peptides (AMPs) Against Clinical Methicillin-resistant Staphylococcus aureus (MRSA)
Authors: Ciandrini Eleonora , Morroni Gianluca , Arzeni Daniela , Kamysz Wojciech , Neubauer Damian , Kamysz Elzbieta , Cirioni Oscar , Brescini Lucia , Baffone Wally , Campana Raffaella 
Published: October 2018

Background:
Antimicrobial research is being focused to look for more effective therapeutics
against antibiotic-resistant infections caused by methicillin-resistant Staphylococcus aureus (MRSA). In
this direction, antimicrobial peptides (AMP) appear as promising tool.

Objectives:
This study evaluated the antimicrobial activity of different AMPs (Citropin 1.1, Temporin
A, Pexiganan, CA(1–7)M(2–9)NH2, Pal-KGK-NH2, Pal-KKKK-NH2, LL-37) against human MRSA
clinical isolates.

Methods:
The Minimum Inhibitory Concentration (MIC) was assessed for each AMP; then, the most
active ones (Citropin 1.1, Temporin A, CA(1–7)M(2–9)NH2 and Pal-KGK-NH2) were tested against
selected MRSA strains by time-kill studies.

Results:
The lowest MIC value was observed for Pal-KGK-NH2 (1 µg/ml), followed by Temporin A (4-
16 µg/ml), CA(1–7)M(2–9)NH2 (8-16 µg/ml) and Citropin 1.1 (16-64 µg/ml), while higher MICs were
evidenced for LL-37, Pexiganan and Pal-KKKK-NH2 (> 128 µg/ml). In time-kill experiments, Citropin
1.1 and CA(1-7)M(2-9)NH2 showed a relatively high percentage of growth inhibition (>30 %) for all the
tested MRSA clinical isolates, with a dose-dependent activity resulting in the highest percentage of bacterial
growth inhibition (89.39%) at 2MIC concentration.

Conclusion:
Overall, our data demonstrated the potential of some AMPs against MRSA isolates, such
as Citropin 1.1 and CA(1-7)M(2-9)NH2, that represents a promising area of development for different
clinical applications.
Design of Patient Specific Spinal Implant (Pedicle Screw Fixation) using FE Analysis and Soft Computing Techniques
Authors: Biswas Jayanta Kumar , Dey Swati , Karmakar Santanu Kumar , Roychowdhury Amit , Datta Shubhabrata 
Published: October 2018

Background:
This work uses genetic algorithm (GA) for optimum design of patient
specific spinal implants (pedicle screw) with varying implant diameter and bone condition. The optimum
pedicle screw fixation in terms of implant diameter is on the basis of minimum strain difference
from intact (natural) to implantation at peri-prosthetic bone for the considered six different
peri-implant positions.

Methods:
This design problem is expressed as an optimization problem using the desirability function,
where the data generated by finite element analysis is converted into an artificial neural network
(ANN) model. The finite element model is generated from CT scan data. Thereafter all the
ANN predictions of the microstrain in six positions are converted to unitless desirability value varying
between 0 and 1, which is then combined to form the composite desirability. Maximization of
the composite desirability is done using GA where composite desirability should be made to go up
as close as possible to 1. If the composite desirability is 1, then all ‘strain difference values in 6 positions’
are 0.

Results:
The optimum solutions obtained can easily be used for making patient-specific spinal implants.