bluuebunny/crossref_metadata_2025 huggingface dataset:
Devir histórico e devir ôntico: sobre a questão existencial e o sentido da vida na visão de Antonio Meneghetti e Viktor Frankl
Authors: Wazlawick Patrícia
Published: October 2017

Verificando que existem resultados educacionais, psicológicos, técnicos, profissionais, acadêmicos, e acima de tudo, pessoais e existenciais para um grupo de 49 jovens estudantes do ensino superior universitário, a partir da realização de uma pesquisa configurada como estudo de caso, exploratória e empírica, de abordagem quantitativo-qualitativa, em três cursos de graduação em uma faculdade privada localizada em município de pequeno porte do Rio Grande do Sul, decidiu-se, por meio desta, estudar teoricamente a relação entre o devir histórico e o devir ôntico construindo um amálgama entre os dois constructos teóricos nos aspectos da questão existencial e o sentido da vida a partir das obras de dois estudiosos: Antonio Meneghetti e Viktor Frankl. Este artigo, sendo uma pesquisa teórica, a partir da pesquisa empírica citada, realiza, portanto, uma discussão sobre o sentido da vida na visão dos dois autores acima citados, na busca de aprofundar a fundamentação teórica sobre esta temática, bem como tecer um diálogo entre aspectos da teoria ontopsicológica e a psicologia do sentido da vida (Logoterapia).
FORMAÇÃO INTEGRAL PARA O PROTAGONISMO RESPONSÁVEL: AS DIMENSÕES DA FORMAÇÃO DO JOVEM NO RECANTO MAESTRO
Authors: Schaefer Ricardo
Published: October 2017

Esta pesquisa de desenvolvimento teórico tem o objetivo de resgatar passagens teóricas e práticas expostas pelo Acad. Prof. Antonio Meneghetti relacionadas à formação de jovens no Centro Internacional de Arte e Cultura Humanista Recanto Maestro, cujos projetos educacionais estão baseados na pedagogia ontopsicológica e epicentrados na Antonio Meneghetti Faculdade. O escopo é identificar as principais dimensões que permitem uma formação integral para o desenvolvimento do protagonismo responsável nos jovens. As fontes de pesquisa englobaram materiais publicados em vida por Antonio Meneghetti, materiais inéditos pertencentes ao acervo audiovisual da Fundação Antonio Meneghetti e pesquisas anteriores que investigaram a temática. A partir desse levantamento, chegou-se a cinco dimensões que, desenvolvidas de modo conjunto, complementar e progressivo, permitem uma formação integral ao protagonismo responsável: o estudo, o trabalho, a alta moralidade, a ciência e a internacionalidade.Palavras-chave: formação integral, protagonismo responsável, pedagogia ontopsicológica, formação de jovens, Antonio Meneghetti Faculdade, Recanto Maestro.
Banking Sector Profitability, Before, During and After Global Financial Crisis: Evidence from a Developing Economy
Authors: Nisar Shoaib , Peng Ke , Wang Susheng , Ahmed Jaleel
Published: October 2017

This study grants empirical support to the fact that profitability of the Pakistani banking sector was reduced during 2008-2009 and among other factors this reduction was attributed to the global financial crisis and resulting increased investments portfolio in total assets. We have used panel data of all Pakistani scheduled banks during 2005-2012. We proved theoretically and empirically that fixed effects model is appropriate for this study. Second stage analysis confirms the above results and shows that the profitability of Pakistani banking sector was higher in pre and post crisis years than, in financial crisis period. Profitability was relatively lower in the after crisis years then in before crisis years because of the residual effects of the global financial crisis. In third stage analysis we found that private and foreign banks were more affected by financial crisis than public sector, specialized and Islamic banks. Our results are robust to alternate measures of profitability. In context of developing countries this study will help bank managers and the regulators to stay better prepared to face any financial crisis in future.  
Science Teachers and Budget Planning for Instructional Resources in Secondary Schools in Nairobi, Kenya
Authors: Oyier Charles Richard , Odundo Paul Amollo , Ngaruiya Boniface , Mwangi John
Published: October 2017

Achieving transformational knowledge based economy as provided for in Kenya’s Vision 2030, requires adequately budgeted for science instructional resources. This is because instructional resources are key in practical work which enhances learners experience and understanding science concepts, hence better learning achievement. This study sought to establish the link between budget planning in secondary schools in Nairobi County to their financial management policies in terms of setting up structures for handling budgetary allocations in a coordinated approach through consultation with staff. It relied on a sampled principals and science teachers from public and private schools in Nairobi County obtained using stratified sampling techniques. Using cognitive based participatory decision making model, the study established that secondary schools have budgeting objectives that take science instructional resources in consideration; science teachers place their budgetary request based on their schemes of work to the budgeting committee and are present during prioritization on departmental list. It also established that systems for projecting revenues and expenditures are established in secondary schools to link policy objective on science instructions and resources and that allocations for instructional resources are specified in school budget in public secondary schools than their private counterparts. In practice, the study recommended that science teachers need to be involved in budgetary decision making and measure be put in place to ensure this happen. It suggested more research on the role science teachers in improving learning outcomes through participation in budgetary decision making.
Discrete Sine Transform-Based Interpolation Filter for Video Compression
Authors: Kim MyungJun , Lee Yung-Lyul
Published: October 2017

High Efficiency Video Coding (HEVC) uses an 8-point filter and a 7-point filter, which are based on the discrete cosine transform (DCT), for the 1/2-pixel and 1/4-pixel interpolations, respectively. In this paper, discrete sine transform (DST)-based interpolation filters (IF) are proposed. The first proposed DST-based IFs (DST-IFs) use 8-point and 7-point filters for the 1/2-pixel and 1/4-pixel interpolations, respectively. The final proposed DST-IFs use 12-point and 11-point filters for the 1/2-pixel and 1/4-pixel interpolations, respectively. These DST-IF methods are proposed to improve the motion-compensated prediction in HEVC. The 8-point and 7-point DST-IF methods showed average BD-rate reductions of 0.7% and 0.3% in the random access (RA) and low delay B (LDB) configurations, respectively. The 12-point and 11-point DST-IF methods showed average BD-rate reductions of 1.4% and 1.2% in the RA and LDB configurations for the Luma component, respectively.
A Semi Analytical Model for Predicting Proppant Screen-Out During Hydraulic Fracturing Unconventional Reservoirs
Authors: Cai Xiao , Guo Boyun , Li Gao , Yang Xu
Published: October 2017

Hydraulic fracturing is one of the most critical techniques to enhance oil and gas recovery in unconventional reservoirs. Screen-out is considered as one of the most serious problems against a safe, effective and cost-saving hydraulic fracturing treatment in unconventional reservoirs. A simple method for predicting the probability of a screen-out is highly desirable. A semi-analytical model is derived in this paper to describe the configuration of proppant pile within the fracture and to predict the time of screen-out. Case study demonstrates a good consistency between the model calculation result and field observations. By conducting sensitivity analysis with the new model, some major factors that affect proppant screen-out are identified such as fluid viscosity, injection rate, proppant density, proppant size, proppant size distribution and the ratio of proppant volume to fracturing fluid volume. Screen-out can be avoided or at least delayed through optimizing these parameters.
Technological Process Reengineering and Optimization of Liquid CO2 Fracturing Based on Fluid Phase Control
Authors: Meng Siwei , Liu He , Yang Qinghai , Xu Jianguo , Duan Yongwei , Chen Shi
Published: October 2017

During liquid CO2 fracturing treatment in PetroChina Jilin Oilfield, CO2 flows through storage tank, booster pump, blender, fracturing pump, and eventually into wellbore and production zone, generating a very complex phase evolution behavior. morphology control of CO2 is a key in liquid CO2 fracturing, as it greatly affects the stability of fluid and sand supply.

Temperature and pressure sensors are positioned at 12 critical nodes in a liquid CO2 fracturing field test for tight oil to provide insight on CO2 fluid phase evolution behavior. Then an analysis of phase behavior at each process node is done, to investigate its influencing mechanism on operation stability, as well as its major control factors. Based on this, the fracturing technological process is optimized and restructured, aiming at the optimization of fluid performance and construction stability.

Results are as follows. 1) Storage conditions of CO2 are inconsistent between different storage tanks, which may cause vaporization of CO2 during low-pressure fluid-feeding stage, thus greatly affect the construction stability. A buffer vessel should be introduced into the fracturing system, between the tanks and boosters, to improve the fluid-feeding stability. 2) The storage temperature and pressurein Jilin Oilfield is much higher than thatin North America, so the boosters contribute little to phase control here. A heat exchanger is a better alternative. 3) When the pressure difference between in-tank and outlet of blender is less than 0.05 MPa, the sand-feeding process is stable. This can be achieved by adjusting phase behavior of CO2, liquid supplement rate to blender and opening degree of butterfly valve.

Phase evolution during liquid CO2 fracturing has been identified, and the fracturing technological process is optimized and restructured based on this. This helps improve the fluid performance and construction stability, and enhances the success ratio and stimulation result of fracturing.
Gas Lift Techniques Modification to Overcome Evolution in Completion
Authors: Izwardy Saesarian , Oscar Edy I Ketut , Wijanarko Andre , Fedriando Fedriando , Ibnu Pratomo Andaru , Firmansyah Nanang
Published: October 2017

Completion type in Vico Indonesia is designed mainly based on the subsurface considerations. Multi-layer reservoir consisting of gas and oil reservoirs related with fluvio-deltaic depositional environment influences the production strategy which will need zone isolation for single or commingled production. Many completion types have been implemented since early development including single or dual selective, monobore, and dual monobore cemented as the most recent completion. There are more than 500 wells drilled and completed using dual monobore cemented completion. This completion type gives constraints on the application of common downhole pump lift. Evolution in the completion type requires a different approach in gas lift technique for oil development.

Many gas lift techniques have been applied to address the completion types. The gas lift techniques include the implementation of conventional gas lift with SPM, poor boy, coiled tubing gas lift, and coiled tubing gas lift with unloader. The first two methods are common for selective completions while the last two are fit for purpose for monobore completions.

The appropriate modification and selection on the gas lift techniques exhibits a real benefit to optimize oil recovery in these various and evolving completion types in VICO. The contribution is around 70% from total oil production while single year gas lift project contributes to approximately 30% of annual production in respective year. Total cumulative production from the application of these techniques is around 10 MMBO.

Modification in gas lift techniques is needed to tackle evolution of completion types. Coiled tubing gas lift with unloader is the newest technique used to enhance the advantage of coiled tubing gas lift application. The modification of gas lift techniques will be described in this paper.
Understanding Crude Properties to Optimize Corrosion Inhibitor Selection and Usage
Authors: Novitasari R. A. , Wincana M. N.
Published: October 2017

Banyu Urip Field is located in Central-East Java, Indonesia where well production fluids are routed from wellheads to processing facilities via interconnected full well stream piping and flowlines. The produced fluids contains high level of CO2 (45% mol) and H2S (1.5% mol). The utilization of carbon steel in the design of piping and equipment makes them susceptible to corrosion. Injection of corrosion inhibitor (CI) is recommended to minimize material degradation, and correct selection of CI is key to ensure corrosion management is effective and efficient.

A comprehensive understanding of produced fluid properties is important prior to CI selection. Various experiments were conducted in high pressure-high temperature Hastelloy autoclaves to simulate process conditions, with support from proprietary company software modeling 7%, 20% and 80% water partitioning in Banyu Urip Oil samples. An oil-water wettability study was also a key factor to predict the threshold water cut at which produced water separates from crude oil and wets the metal surface of the flowlines.

The experiments revealed potential corrosion rates that could be expected in Banyu Urip flowlines for a range of production scenarios. Results also demonstrated that a decrease in liquid shear stress yields a decrease in corrosion rate; where as a decrease in temperature yields an increase in corrosion rate due to reduction of FeCO3 scale protection. This FeCO3 scale protection provides self-inhibiting properties which are keys to selection and optimization of CI.

Through the oil-water wettability study we can determine an optimal time where the metal surface is wetted by water and thus requires CI to control corrosion. This will help in determining the most cost effective corrosion management programs for the facilities.

This paper will provide an overview of the Banyu Urip corrosion inhibitor selection process; describe the corrosion experiments conducted to verify the crude properties and the oil-water wettability studies to optimize the injection of CI.
Best Practice of Increasing the Income and Reducing the Expenditure, Lowering Cost and Improving Benefit on the Brown Oilfields
Authors: Liu H. , Meng S. , Zhao Z. , Yan J. , Yao Z.
Published: October 2017

Over-developed oilfields in East China have gone through suffering situations induced by high cost in recent years. The trend of resource deterioration is irreversible and the deterioration leads to the increasing difficulties in oil and gas exploration and development. The rate of return-on-investment continually decreases resulting from over-rapidly increasing properties, and ever-rising facility depreciation and damage. The space for increasing income and seeking profit is further narrowed by low oil price. These oilfields now move into the period that has huge obstacles to increase profit, confronted with more difficulties in obtaining economic reserves and profitable production. Now the development in over-developed oilfields has stepped into double-high phase, meaning that to avoid ineffective or poorly effective measures and control the fundamental indices like the rise of watercut, natural decline, and so on play the key role in improving development profit. It is necessary to accelerate the build-up of production capacity and enhance reserve, production, and the rate of return-on-investment by actively reforming techniques for the formation of a series of new ones on enhancing oil recovery, as well as advancing the four-unified-into-one management mode of merging production and management, investment and cost, reserve increase and production build-up, and research and production. The concept of focusing on reserve and production must be further switched, meanwhile profit must be realized in all the ingredients of exploration and development during their whole processes, and efficiencies must be maximized. The burden of production and management is relieved, and the focus is switched to profit in an overall and complete way by further recognizing that investment today is tomorrow's cost and strictly controlling property scale to prevent its excessive increase.
Application of Quantitative RBI on Residual Fluid Catalytic Cracking
Authors: Shuang Liang , Duhui Lu , Fangwei Luo
Published: October 2017

RFCC is one of the most important processes of petrochemical industry and is also a frequent accident process due to the inflammable and explosive material and intermediate product. Optimized risk management in RFCC plays a great role in guaranteeing exploration and production work safely and smoothly. On this premise, the Risk-Based inspection (RBI) was presented and widely prevailed in petrochemical enterprises.

Optimized RBI on RFCC starts at collection of inspection data followed by identification and assessment of damage mechanism and failure modes. Equipment risk is calculated with the help of Orbit-onshore (DNV) software. According to quantitative results, item's risk level are assigned and prioritized by risk matrix so that critical one which would be inspected thoroughly is noticed. Eventually, an appropriate inspection program for RFCC is designed with numbers of proper measures to extend interval by assigning resources of inspection and maintenance.
Downhole Permanent Magnet Synchronous Motor PMSM Drive PCP - Wide Range of Speed, Output and High Efficiency
Authors: Zhongxian Hao , Guobin Zhang , Shijia Zhu , Lixin Zhang
Published: October 2017

Rod-tubing wear and suck rod failure are two serious problems in many oil fields, which take 45% of the whole workover. Because of the problem, in some area, the average mean-time-between-failure is only 200 days. The workover costs lots of money, not including the loss of oil production. A rodless artificial lift system, electric submersible progressive cavity pump (ESPCP), was developed and had been successfully deployed. This paper focuses on the ESPCP technology and field application.

The system included a progressive cavity pump driven by a downhole permanent magnet synchronous motor, which allowed adjusting the rotation speed between 50-500 rpm. a motor protector and a flexible shaft connecting the pump and the motor protector. More than 20 ESPCP systems has been deployed. The power of these motors was 9-15 kilowatts. The average pump setting depth was 1100 meters and the average production rate was 7-70 cubic meters per day. The application results showed that the average pump efficiency was 75.2% and the system could save more than 20% of the electricity power. In some area, the average time between workovers from 192 days of the traditional sucker rod pump to more than 400 days.

The longest running life was more than 500 days. By using this technology, the production and workover cost could be greatly saved and increased production days can be increased accordingly. Moreover, the system was located at the bottom of oil well, so less site occupation, more safety and less noise pollution to the environment were achieved.

The ESPCP system is of great of significance for some special wells such as directional well, highly-deviated well, it also can avoid the pollution in wetland and floodplain field.
A Downhole Constant Flow Nozzle Research in Waterflooding Wells
Authors: Hongwei Zhang , Jinzhong Wang , Jiaqing Yu , Fuchao Sun , Jiuzheng Yu
Published: October 2017

Waterflooding has been proved one of the most effective IOR method for mature field. Commingle waterflooding may result in quick breakthrough. Zonal water injection is used to decrease water-cut rise. Our aim is to make zonal flowrate constant. However, zonal flowrate usually change duo to reservoir feature and inter-layer influence. Also wellhead pressure change frequently which lead to flowrate change a lot. This paper introduces a new downhole constant flow nozzle which can keep zonal flowrate constant under the condition of pressure change. And the flowrate can be adjustable on line by instrument and then the nozzle can also keep current flowrate constant at that opening position. In this paper, a downhole constant flow nozzle in waterflooding wells is introduced. A constant nozzle is placed in each layer permanently. The nozzle has two chokes. One is used to adjust flowrate on line by instrument. The other choke is used for automatic flowrate control. The nozzle can keep flowrate constant by adjusting the opening of the choke automatically. The nozzle was also composed of arm, adjusting mechanism and two chokes. The effect of flowrate automatically control can be checked by instrument controlled by cable. The downhole constant flow nozzle has been implemented in the simulation well in jidong, PetroChina. It can realize two things. The first one is that the nozzle keep flowrate constant when tubing pressure change. Tests have been done at different position where the flowrate was adjusted from 10 to 50m3/d. Then pressure was changed from 1MPa to 10MPa. The lab test results show that the flowrate can be kept constant automatically within the accuracy 10%. In Jidong, if the accuracy can be controlled within 20%, it can meet the need of water allocation scheme. The chief merit of the nozzle is that it can not only be adjustable through instrument, but also can keep flowrate constant at any opening position. Even if the constant nozzle fails to work, the nozzle can still finish normal water injection. The test and adjustment efficiency can be improved by 15% by using this nozzle for waterflooding wells.
Cost Effective EOR in Heavy-Oil Containing Sands by Gas Injection: Improvement of the Efficiency of Foamy Flow and Pressurization
Authors: Soh Ye Ji , Babadagli Tayfun
Published: October 2017

Primary recovery of heavy-oil is remarkably low due to high viscosity and low energy by solution gas exsolution to drive the oil. Gas injection to improve foamy flow and also to dilute the oil in such reservoirs has been proposed as a secondary recovery method. However, because of the high costs of injected gases, efforts are needed to optimize the process by selection of proper gas type (or gas combinations) and suitable injection scheme. To achieve this goal, an experimental procedure was followed with rigorous analyses of the output. A 1.5 m long and 5 cm diameter sand-pack was first saturated with brine, which was replaced with dead oil. Then, gas solvents were injected to dead-oil containing core-holder until nearly reaching 500 psi followed by a two-day soaking period. Pressures all along the sand-pack were recorded with eight pressure transducers. Different combinations of various gas solvents (methane, CO2, and air) aiming to select the most competitive and economic formula were tested with a certain set of pressure depletion rates.

The physics of the foamy oil flow for different solvent mixtures and depletion conditions were analyzed using pressure profiles acquired, recorded oil/gas data with time, and gas chromatography and SARA analyses of the produced gas and oil. Three huff-n-puff cycles were applied. Compared with other light hydrocarbon solvents and carbon dioxide, air has its high advantage in terms of accessibility and lowered cost. Hence, attention was given to air that was mainly used to pressurize the system and increase oil viscosity due to oxidation process with an expectation of better foam quality when injected with other gases such as CO2 and methane. Methane (CH4) yielded the quickest response in terms of gas drive but, in the long run, CO2 was observed to be more effective technically. Air was observed to be effective if mixed with CO2 or methane from an economics point of view. To sum up the results, air Huff-n-Puff (HnP) followed by 2-cycles of CH4 HnP yielded 36.21% recovery, while air HnP followed by 2-cycles of CO2 HnP delivered 30.36% oil. When the gases are co-injected, air 50%-CO2 50% and air 50%-CH4 50% recovered 29.85% and 23.74% of total oil-in-place, respectively.
Massive Fracturing Evaluation to Different Well Patterns for Daqing Tight Oil Reservoirs
Authors: LI Ang , Zhuang Xiangqi , Wen Heng
Published: October 2017

Daqing oilfield has been produced for more than 50 years. Oil production from conventional oil pools is dropping significantly. But in recent years, massive fracturing technology were applied to difficult tight oil reservoir and unconventional gas development. More and more difficult reserves can be unlocked with this technology and that will revive oil production in Daqing field in near future, because the estimated recoverable tight oil & gas is more than conventional oil produced in past 50 years. To develop these tight oil reservoirs such as Zhou-6 and Shu-2, water injection and re-frackstimulation are required to provide economic production rate for running field under low oil price market environment.

Ageneric workflow combining reservoir qualities and engineering parameterswas proposed in this paper. The advantage of this new workflow can consider all aspects and interactions from historic reservoir pore pressure, saturation and stress to frack pumping schedule, fluid and proppant volume which will impact re-frack fracture network development in great detail and production behavior of re-frack well in an integrated model and simulation process. At the same time, how varying well spacing and injection schema impact the fracture complexity and stimulated reservoir volumeof massive re-frack stimulations.

This case study concludes that an integrated new workflow from reservoir characterization, geomechanics analysis, stimulation engineering to history matching with calibration of micro-seismic data and production performance data is possible and feasible to precisely simulate re-frack wells production behavior under varying well patterns and water injectivities.
Reservoir Characterisation Using Permanent Distributed Temperature Sensing in Coal Seam Gas Development: Success and Challenges in the Surat Basin
Authors: Bottomley W. , Furniss J. P. , Oguche I. , Konopczynski M.
Published: October 2017

This paper discusses the use of permanent Distributed Temperature Sensing (DTS) using optical fibres for flow zone allocation in Coal Seam Gas (CSG) production wells.

In a commingled well the allocation of total well production to the multiple stacked reservoir units is extremely important. Understanding which zones are most productive can influence future development decisions and operational practices. Additionally, the subsurface reservoir model can be calibrated and verified from the data, improving the accuracy of any forecast derived from the model.

At QGC, well completion design has focused on simplicity to drive efficiency in the execution of the ca. 2,500 wells drilled so far. These open hole completions have been run with a pre-perforated liner and no external packers to separate formations. This adds uncertainty to the interpretation of results from conventional wireline production logging tools (PLTs) run inside the pre-perforated liner. To perform a conventional PLT, the down hole pump for dewatering must be pulled, requiring a rig and making flow allocation data acquired by PLT very costly. DTS is seen as a viable alternative to PLTs, with the measurement fibre run permanently on the outside of the casing or tubing. It can remain in the well during pump operation and gather data throughout the life of the well. Typically, at QGC, a recording is made every 6 hours and is transmitted to a cloud based database for immediate visualisation.

Since a temporary single day DTS installation was trialled in 2014, QGC has run 11 permanent fibres across its Surat CSG development. This has yielded valuable information on production allocation and depletion trends. There have also been a number of challenges encountered. These include interpretation of dual phase flow, and identifying the correct geothermal gradient for interpretation. The advantages and disadvantages of casing conveyed versus tubing conveyed DTS installations are also discussed.
Real-Time Application of Integrated Well and Network Models through Smart Workflows for Optimizing and Sustaining Production Targets in an Area of Kuwait's Greater Burgan Oil Field
Authors: Al-Shammari B. , Rane N. M. , Desai S. F. , Al-Rabah A. A. , Pandey M. , Shankhdhar S. , Chacko R. , Jagannathan R.
Published: October 2017

The asset optimization system deployed in Kuwait's Greater Burgan oil field involved development of an integrated model of the processing facility, flowlines and wells. The objective of the integrated asset model is to achieve production optimization from the network considering well performance and restrictions combined with the limitation imposed by the surface piping network and the processing facilities.

The Burgan oil field's integrated digital field (KwIDF) automation system monitors well and plant instruments in real time from SCADA and DCS systems. It uses real time wellhead pressure and water water-cut measurements for virtual metering and calibration of the well and network models. To maintain the facility production target, various built-in production optimization scenarios are run daily and the results are visualized through smart dashboards in the state-of-the-art collaboration center. The results are shown as new optimized set points for choke or header changesto achieve facility production targets. The new set points can be automatically passed on to the SCADA system for implementation after quick validation by the stakeholders.

The paper provides new insights on the challenges of effectively running an integrated well and network model in an automated workflow through full loop, from measurement to implementing recommendations at wells and the production facility. Examples are presented on how the workflow has been used in quick analysis and decision making to optimize daily production and achieve sustainable targets in one of the production facilities at Greater Burgan field in Kuwait.
Formation Evaluation by Sourceless Logging While Drilling: NMR Case Study from Bohai Bay
Authors: Xu Jinxiu , Tan Lv , Cui Yunjiang , Liu Xiaogang , Liu Huan , Coman Radu , Tietjen Holger , Wei Gang
Published: October 2017

Environmental concerns have resulted ina ban onnuclear logging-while-drilling (LWD) methods containing radioactive sources and of oil-based mud in Bohai Bay, China, which is an environmental sensitive area. To avoid the risk of a radioactive source falling into the wellbore and to keep the cost of the logging program low, nuclear magnetic resonance (NMR) LWD was used as a sourceless standalone measurement, primarily to estimate the porosity and to detect permeable intervals in the Jinzhouoilfield.

This paper presents the potential and limitations of NMR-LWD in a challenging drilling environment. The resistivity of the drilling fluid was often below 0.02 ohm·m and the mud was often more than 30 K colder than the formation. These two conditions can lead to an underestimated porosity, if the NMR data is not properly corrected. Achieving rapid drilling progress was an additional goal. One borehole was drilled with a rate of penetrations (ROP) between 30 m/h and 50 m/h for analyzing the effect on data quality.

The processed NMR data shows that the high ROP has no detrimental impact on the accuracy of NMR porosity results, but, as expected, the vertical resolution is directly related to the ROP. By applying the temperature and resistivity corrections, the standalone NMR-LWD measurement compares well with offset porosity based on density-neutron logging and provides reliable data for the total porosity and for all other formation evaluation applications based on NMR data. In Bohai Bay the corrected NMR data have been successfully used to accurately detect in real-time permeable intervals bearing light oil in a complex high-porosity shaly-sandstone multilayer reservoir as well as gas intervals. In addition, the NMR data have been used to quantify bound water and movable fluids and to predict the reservoir effectiveness and productivity.
Real-Time Sanding Assessment for Sand-Free Fluid Sampling in Weakly Consolidated Reservoirs, A Case Study from Bohai Bay, China
Authors: Zhang Guoqiang , Tan Zhongjian , Khaksar Abbas , Gui Feng , Wang Shanshan , White Adrian , Lei Guowen
Published: October 2017

Wireline formation fluid sampling in weakly consolidated, heavy oil reservoirs has been unsuccessful in appraisal wells in the Bohai Bay area, offshore China. Poor sampling and prolonged testing time were unacceptable from both operational and formation characterization points of view. The challenges involved the production of solids during fluid sampling, contamination as well as poor and unreliable pressure testing.

An integrated study was conducted to build a fit-for-purpose geomechanical model for the study field using drilling data, well logs, formation and drill stem testing data and sanding observations in several offset wells. An analytical sanding evaluation methodologywas used and calibrated with the observed sand production in the study wells. The calibrated model was then used in a near-real time basis for new wells to optimize the sampling depth points and drawdown pressures to avoid sanding while sampling and also to speed up the sampling time to reduce operation time and costs. The aim was to use higher drawdowns and faster testing while also avoiding intervals where sand-free drawdown may not be possible.

Using the workflow in new wells has resulted in sand-free sampling at higher drawdownsas well as faster sampling speeds. In contrast, in wells where the rock mechanical aspects of fluid sampling and the root cause of sanding while sampling were not incorporated into the logging and formation testing operations, the sampling failed again due to sanding issues despite the moderate drawdown and slower sampling rate.

Real-time integrated geomechanical and formation evaluation analysisresulted in delivering sand-free fluid samples, saving 30% rig time, and more successful and reliable pressure and fluid sampling for accurate reservoir and fluid characterization.
A Comparative Workflow for Different Hydraulic Fracturing Techniques in the Western Desert Oil Fields of Egypt
Authors: ElHamid Ahmed Abd , Abbas Mohamed , Hamed Eslam , Ghareeb Mohamed , ElSebaee Mohamed , Sweedan Ahmed , Sabet Ahmed
Published: October 2017

"When everything else fails, frac it" was the sentiment expressed by most engineers who were working on hydraulic fracturing during the late 1970s. This statement indicates how important the hydraulic fracturing technique is, not only in stimulating, and thus greatly increasing, the well's production, but also as a powerful tool to manage the field development. Hydraulic fracturing has become the most applicable and reliable reservoir stimulation technique in all reservoir rock types, even more than the matrix acidizing techniques. Starting from 1940s, when the first hydraulic fracture was performed, until now, the improvement in the hydraulic fracturing technology has never stopped. Currently, the state-of-the-art technology in hydraulic fracturing is the channel fracturing technology or, in other words, open channel fracturing. This is a unique technique of pumping a treatment that helps in forming channels within the proppant pack in the fracture, which improves the fracture conductivity and well productivity.

This study consists of two main parts. The first part is dedicated to the evaluation of the channel fracturing technique by comparing it to conventional fracturing. This comparison depends on three primary evaluation methods. First, well testing data obtained for conventionally fractured wells and wells in which the new technology was implemented were evaluated. Second, the actual production data for offset wells, which were fractured either by conventional technique or by the new channel fracturing one, were analyzed. Finally, an economic comparison of the techniques and an assessment of the gain that can be obtained from the new channel fracturing technique over the conventional one were performed.

After the evaluation and comparison, a statistical analysis was conducted based on a sample consisting of more than 50 wells that were fractured using the channel fracturing technique. This statistical analysis aims to attain the channel fracturing treatment parameters that lead to the best corresponding production results.

These two main parts represents a full evaluation and optimization process that gives a complete picture of the channel fracturing technique and an assessment of the new technique. The assessment considers how to achieve best performance based on a sound statistical analysis constructed by actual day-to-day data and well performance. The assessment proves the economic and production value of the new technique over the conventional fracturing technique, which failed to give the same values.
Development and Application of Pulley-Free Directly-Connected Hydraulic Pumping Unit
Authors: Ye Qinyou , Wang Feng , Wang Yucai , Zhu Yongzhi , Xu Jianguo , Li Xingke , Yang Gao
Published: October 2017

Pulley-free directly-connected hydraulic pumping unit lift technology, developed based on the characteristics of Jilin Oilfield, can be applied to produce cost-effectively the difficult-to-produce reserves, and to improve the low fluid production and reduce the high energy consumption of developed oilfields.

Featuring low cost, low energy consumption and high efficiency with one unit serving several wells, this technology can meet the lift demand of different flow rate at different well depth. The hydraulic pumping system consists of three discrete units, namely main frame, hydraulic station and electric cabinet. The piston and sucker rod of the main frame are connected directly. When the system works, the pump of the hydraulic station provides power for the hydraulic cylinder of the main frame, which drives directly the reciprocating movements of the sucker rod to lift fluid via the reciprocating movements of the piston. The centerline of the main frame coincides with that of the casing, and so there is no unbalance loading. Substituting for the polish rod, the piston rod of the pumping unit connects directly with the sucker rod. The elimination of pulley, wire rope, rope hanger and packing box minimizes the wear parts of the system. Besides, when the system is in service, the main frame can be disassembled like tubing, having no impact on workover. The electric cabinet acquires signals via the displacement sensor and pressure sensor on the main frame and processes them, with such information as indicator diagram, stroke and stroke times displayed on the touch screen.

The ground equipment in this technology has light weight, which is about 15% of a beam pumping unit of the same model. With this technology, long stroke, low stroke times, big pump size lift, reduced rod-casing wear, prolonged maintenance free period and improved operation efficiency can be realized. Compared with existing pumping units, its investment in equipment is less. The cost of a twin well system can be reduced by more than 30%, and the energy conservation at the same fluid production rate is above 25%.

By December 2016, 24 wells of different depth in Jilin Oilfield had been subjected to pilot test successively. The "one driving one" hydraulic pumping units applied to two wells had operated stably for more than 700 days free of trouble, and the pumping efficiency had been improved by 35% compared with other types. The successful application of this system has verified its overall stability and its adaptability to the extremely cold environment in the northeast China. The "one driving two" hydraulic pumping units had been applied to 22 wells, and the test results show that both the process flow and the system are stable.
Optimizing Oil Recovery through Microbial Injection to Support the Increasing Demand for Oil in Indonesia
Authors: Budiharjo Harry , Suhascaryo Nur , Nugroho Handika Agung , Saputra Benny Ariandy
Published: October 2017

The method that uses microorganisms to increase oil recovery from reservoir rocks is called Microbial enhanced oil recovery (MEOR). Using this method, the microorganisms are injected to the reservoir and produce the metabolic product which is used in MEOR. There are 6 main metabolic products (bio-products) that can be effected to the reservoir fluid and rock. The 6 main bio-products are bio-surfactant, bio-polymer, bio-mass, bio-solvent, bio-gases and bio-acid. Every bio-product has a different effect on the reservoir and is produced by different microbes, with its purpose being to decrease the residual oil saturation that is left behind in the reservoir rock.

Bio-surfactant can reduce the interfacial tension between oil and the formation water and bio-polymers control the mobility of water that is used in waterflooding. Biomass can plug the reservoir pores and then change the flow direction of fluid flow in the rock. Bio-gas increases reservoir pressure and then forces the oil out of the rocks. Bio-acid can dissolve rock particles and open pore mouths, thus increasing rock porosity and permeability and allowing more fluid to flow, especially in Limestone.

A MEOR field trial was successfully applied at ‘X’ Field X in Indonesia, involves 10 wells. It can decrease oil viscosity, increase in Oil API Gravity and decrease of the oil pour point. Oil production rate increased from 8 to 66%. Scale is observed as a disadvantage of successful MEOR. The results from this field trial demonstrate that MEOR is potential and offers some benefit to increase oil production.
Planning and Execution of ERD Development Wells Project in Myanmar
Authors: Atemin Azizul , Ramasamy Kesavan , Jainuddin Mohamad Nor , Ong Chongyew
Published: October 2017

This paper highlights the top quartile performance well delivery of Yetagun In-fill Phase 6 drilling campaign in Yetagun gas field, offshore Myanmar. Drag, Torque, Hook load and Stand Pipe Pressure that occur in an ERD well is typically higher than conventional well due to long horizontal displacement and high lateral inclination angle. Hence, the importance of planning process, execution, drilling practices and lesson learnt which essentially resulting in a successful drilling operation were discussed in the paper.

PETRONAS Carigali Myanmar Limited (PCML) successfully drilled three in-fill wells: YA-01, YA-05, and YA-12ST1 which were classified as ERD based on extended reach industry experience plot with the objective to maintain the gas production rate. Excellent planning process and good teamwork among the project team members were required to tackle all the technical issues as well the environmental and logistical challenges. The unique and challenging design for YA-05 as compared to others where it has the longest tangent length which fall within 70-80° sail angle. YA-01 and YA-12ST1 were classified as ERD medium reach class design, thus require specific ERD drilling, hole cleaning, ECD monitoring, tripping and backreaming practices to ensure success of the well. The challenges in designing ERD wells were multiple such as high torque and drag, loss circulation, well collision, differential sticking, borehole instability, hole cleaning, longer open hole interval, high stand pipe pressure and high temperature. YA-12ST1 well was planned with sidetracking design utilizing whipstock and hence, tortuous wellpath which leads to high dogleg at the sidetrack point need to be considered. Losses of circulation were observed from historical development campaign of the field. Thus it was essential that extra precautions have been prepared for efficient hole cleaning and consistent penetration control. Other challenges attached with the recommended practices to overcome them including wellbore instability, differential sticking, drag and friction factors were analyzed further in this paper.

In conclusion, this paper serves as a reference for future ERD well planning and execution as the overall drilling campaign achieved excellent well delivery performance in term of cost and time. This campaign has been successfully completed with remarkable achievements such as the first semi-submersible tender-assisted drilling rig used by PETRONAS group, huge total cost saving, zero lost-time injury, and successfully secured the reservoir target and meet the gas volume target.

The novelty of the successful Yetagun Phase VI development wells project yielded good practices, technology used and excellent project planning that can be applied in future projects. This paper also can be a reference for future ERD well drilling in Myanmar.
Experimental Investigation on a Novel Organic-Inorganic Crosslinked Polymer Gel for Water Control in Ultra-High Temperature Reservoirs
Authors: Liu Yifei , Dai Caili , You Qing , Zou Chenwei , Gao Mingwei , Zhao Mingwei
Published: October 2017

This article presents a novel organic-inorganic crosslinked polymer gel, which uses resin-silicate as the organic-inorganic crosslinker, to extend the temperature limitations of currently used polymer gels for water control in mature oilfields. The gelation performances, including gelation time, gel strength and thermal stability, were studied, and the optimum composition was selected by study of gelation performances. Results show that with increase of the concentrations of components, gelation time became shorter and gel strength was improved. And the gel system was stable after 90 days at 140 °C. The optimum composition of the gel system was selected as: 4~7 wt% resin and 2~5 wt% silicate with 0.1~0.3 wt% polymer. Meanwhile, differential scanning calorimetry (DSC) measurement was used to investigate the maximum tolerated temperature of the gel. The results showed that the chemical bonds of the gel began to break at 156 °C, which indicated that the gel can resist high temperature up to 156 °C. At last, environmental scanning electron microscopy (ESEM) microstructure and fourier transform infrared spectroscopy (FTIR) spectrum of the gel were studied to analyze the gelation process and investigate the mechanism for temperature resistance. The three-dimensional network microstructure of the resin-silicate crosslinked polymer gel was more compact and more uniform than the gel prepared without silicate. The formation of silicon-oxygen bonds (Si-O) increased the crosslinking density and temperature tolerance of the gel system.
Subsea Technology - Multiphase Pumping
Authors: Anwar Zeeshan
Published: October 2017

Subsea gas compression and pumping technologies have been identified as a solution for accessing gas reservoirs that may be otherwise either inaccessible or economically unfeasible to drill. Subsea stations offer a fast-track development solution with flexible, multi-phase deployment, and other inherent advantages whilst filling this application. Pumping stations require a significant amount of process equipment improvements and integration solutions; however, we will focus here on the rotating machinery, process pumps in specific. In the present research, all available operator or manufacturer's reports and published papers are reviewed and a criterion is developed for subsea pump selection base on:

The conventional subsea separation system is compared to a multi-phase pumping one. All applicable types of subsea pumps including Helico-Axial (HAP), Twin Screw Pump (TSP) and Electrical Submersible Pump (ESP) are compared. All parameters in pump type selection such as Gas Volume Fraction (GVF), water cut, differential pressure, head, flow rate, fluid viscosity, RPM, sand content, water depth, Opex, Capex, reliability and asset life is discussed. Material selection as a critical part of the pump selection is studied thoroughly.