bluuebunny/crossref_metadata_2025_split huggingface dataset:
Conventional radiotherapy of localized right side breast cancer after radical mastectomy: development of innovative “field in field” technique
Authors: Marošević Goran , Ljuca Dženita , Fazlić Semir , Ramić Anela , Rahimić Hidajet 
Published: February 2015

Introduction: The aim of this paper is to study the distribution of the therapy dosage applied by a modified conventional “field in field” technique and compare it to the distribution of the dosage applied by the standard conventional technique.Methods: The study included ten patients with right side breast cancer, after they were exposed to radical mastectomy and chemotherapy. Radiotherapy dosage of TD 50 Gy in 25 fractions was applied to the anterolateral side of the right thoracic wall, with two opposite conventional tangential fields by the linear accelerator Elekta Synergy and the energy of 6 megavolts (MV). A delineation of the target volume (CTV – Clinical Target Volume) was done within conventional fields. At the XiO system for planning we included additional fields within the existing conventional fields, which was the so called “field in field” technique. On the basis of CTV the Dose Volume Histogram (DVH) was calculated for conventional and “field in field” plans. VD90%, VD95%, VD107%, VD115%, CI and HI were calculated for both techniques. Means were pared with the paired Student's t-test. The results were considered significantly different if p<0.05.Results: VD90% and VD 95% were significantly higher for the “field in field” technique. Therefore, CI also favored the “field in field” technique (p=0.02). There was no difference in VD107% and VD115% between the compared groups. Consequently, there was no statistically significant difference in HI (1.13±0.03 vs.1.13±0.03, p=0.06).Conclusion: Conventional postoperative radiotherapy of localized right side breast cancer by “field in field” technique provides excellent coverage of the target volume by radiotherapy isodose.
Influence of osteoporosis risk faktors on bone mass loss in postmenopausal women
Authors: Kapetanović Amila , Avdić Dijana , Marković Katarina , Teskeredžić Ata , Basarić Mustafa , Lokmić Eldan 
Published: February 2015

Introduction: Estrogen deficiency plays a critical role in the development of osteoporosis. However, some other factors may contribute to bone loss as well. Aim: To show presence of osteoporosis risk factors and to examine its influence on bone mass loss in women with normal menstrual history.Methods: The study included 30 postmenopausal women, ages from 50 to 65 with osteoporosis who entered into menopause before the age of 45, and 30 postmenopausal women, ages from 50 to 65 with osteoporosis who had normal menstrual history. Presence of risk factors has been calculated for both groups and statistical significance of differences between two groups presented.Results: In the group with normal menstrual history 33.33% women had low level of physical activities, 56.66% suffered from insuficient intake of calcium, 63.33% of women were active smokers. Body mass index bellow 19 had 6.66% women, insuficient exposure to the sun was registered in 60%, and 23.33% women were either taking medicaments or had diseases that could cause osteoporosis. Statistical significance of differencies in presence of certain risk factors between two groups was registered for : insuficient daily intake of calcium (p <0.001), insuficient exposure to the sun (p<0.001), and smoking (p <0.001).Conclusion: Results of the study indicate high presence of osteoporosis risk factors in women with normal menstrual history and indicate influence of certain factors (calcium, sun exposure, smoking) on occurence ofosteoporosis in this group.
Etiological factors as predictor of rehabilitation in patients after carebrovascular insult
Authors: Tanović Edina , Čelik Damir 
Published: February 2015

Introduction: Cerebrovascular insult (CVI) is acute or sub-acute occurrence of symptoms which signal death of cerebral cells caused by localized disruption of arterial circulation in the brain. The goal of this study is toinvestigate whether ischemic or hemorrhagic CVI can be used as predictor of rehabilitation.Methods: A retrospective study was conducted in the period from January 2009 to the December 2009 and as a source of data we used medical records. The study included 89 patients who had CVI and who werehospitalized at the Clinic for Physical medicine and rehabilitation, Clinical Center University of Sarajevo (CCUS). We analyzed socio-demographic variables such as gender and age and clinical variables: the diagnosis,the length of stay in hospital (LOH), and Barthel index (BI) at admission and discharge from hospital.Results: Out of 89 patients, 78/89 (87.6%) were patients with ischemic CVI (group A), and 11/89 (12.4%) with hemorrhagic CVI (group B). There was not a signifi cant association between the gender and type of CVI[(χ2(1)= .041, P> .05]. There was a statistically signifi cant difference in median of length of hospitalization (LOH) between two groups (U=186.5; z=-3,025; P= .002). There was not a statistically signifi cant differencein median of BI at admission (U=317.0; z=-1,399; P= .162) and discharge (U=319.0; z=-1.374; P= .169) between two groups.Conclusion: Patients with hemorrhagic CVI have a longer stay in hospital and consequently more expensive cost of treatment.
Transfusion treatment impact in the improvement of haematological parameters in patients with gastrointestinal bleeding
Authors: Bunjaku Iliriane , Zhubi Mimoza , Zhubi Bukurije , Kryeziu Emrush , Zeka Sadik 
Published: February 2015

Introduction: Transfusion treatment (TT) is necessary in patients with gastrointestinal bleeding (GIB) for lost blood substitution. This study was aimed at assessing the changes in haematological parameters (hemoglobin, hematocrit, red blood cell count, white cell count, platelet count and prothrombin time) before and after TT in anaemic patients with GIB in order to analyse the effect of this treatment.Methods: There have been included 293 patients with GIB (the average age was 57.3, ranged from 18-89 years) who were treated with TT at the Internal Clinic at the University Clinical Center Prishtina during oneyear period. Data for applied blood product and results of the coagulation screen (PT) were collected from the Kosovo’s Blood Transfusion Center (KBTC).Results: TT has been carried out in 404 episodes, with 714 units of concentrated red blood cells (78.6%), 189 units of fresh frozen plasma (20.8%) and concentrated platelets (0.6%), with an average dose 3.1 fortransfunded patients. Average values of Hb before and after TT were 71.8 g/L and 81.4 g/L, respectively; while the average values of hematocrite before and after TT were 22.9% and 25.6%, respectively. The averageerythrocytes count before TT was 2.6 respectively after treatment 2.8(p<0.0001). The PT was carried out in the 43% of patients with GIB before treatment with FFP, but after that only in 2% of cases.Conclusions: Having in mind difficult clinical and unsustainable situation in patients with gastrointestinal bleeding, the Transfusion Treatment resulted in the considerable improvement of the specific blood indicators.
Topical Treatments Used by Breastfeeding Women to Treat Sore and Damaged Nipples
Authors: Buck Miranda L. , Amir Lisa H. , Donath Susan M. 
Published: February 2015

Background: Nipple pain and trauma are frequent complaints of new mothers, and a variety of treatments have been proposed and investigated for efficacy. Numerous studies have examined the efficacy of nipple creams, but there is no published data describing patterns of use in
breastfeeding women.Aim: To describe the use of topical nipple treatments by a cohort of first-time mothers in AustraliaMethods: A cohort of 360 nulliparous women were recruited in Melbourne, Australia, and the question, “In the last week, have you used any creams
or ointments on your nipples?” was included in a questionnaire on breastfeeding practices administered at 6 time points.Results: In the first week after giving birth, 91% (307/336) of women used a topical treatment on their nipples. The most popular treatment was purified
lanolin, with nearly three quarters of women (250/336) reporting its use. At 8 weeks postpartum, 37% (129/345) continued to use topical treatments, and 94% (320/340) of women continued to breastfeed.Conclusion: Widespread use of topical nipple creams is concerning not only because
it may indicate a high rate of nipple pain but also because this is a disruption to the natural environment where the newborn is establishing breastfeeding.
Increasing Sucker Rods' Working Capacities
Authors: Telli Francisco Diaz 
Published: February 2015

Technology Update
Artificial lifting systems are being pushed to their operational limits, given the more demanding field operating conditions that require deeper wells and higher production flows. Over the years, the number of secondary-recovery and nonconventional oil projects has increased, and more is being asked of rod pumping (RP) and progressive-cavity pumping (PCP) systems.
Both pumping systems have found the sucker-rod string to be one of their weakest links. Stress analysis and failure statistics for different parts of sucker rods have found the weakest point to be located in its coupled connection. Rod-pin and coupling failures have become common problems in fields, making it clear that the fatigue resistance of the connection is inferior to the fatigue resistance of the rod body.
Several potential solutions designed to increase rods’ working capacities have been attempted, but none of them attacked the problem genesis: the connection. Recently, however, a premium-connection rod has been developed with a new thread design that has demonstrated very positive results in reducing connection fatigue (Fig. 1).
Design Process
Finite element analysis (FEA) is a numerical tool used to verify designs before field testing can be performed, and with FEA, the most significant design constraints of conventional rod connections were analyzed as a basis for developing the new premium connection design.
The main points addressed in the development of the new design were the following:
Loosening tendency of the connection because of a gap between threads. This gap allows movement between coupling and pin threads when rods undergo compression and/or shocks.
Permanent deformations of the thread (as verified by FEA) during makeup and well operations. These deformations make crack propagation more likely. They also result in a difficult makeup operation when repeating displacements.
Nonuniform stress distribution in thread profile generates regions of high stress concentration and, as a result, makes the pin and coupling more susceptible to the appearance of cracks (also verified with FEA).
High reliance on the makeup operation because both overtorque (increase in the stress level) and undertorque (stress concentration during well operation) are harmful for the connection and produce failures in sucker-rod pins and couplings. In conventional design, thread effectiveness is highly dependent on the cleaning operation before the string is run into the well and an inefficient makeup can easily result and later produce failures.
Technology Focus: EOR Performance and Modeling (January 2010)
Authors: Bai Baojun 
Published: February 2015

Technology Focus
The demand for oil continues to grow, and it is forecasted that oil will continue to dominate the world share of energy supply for the next 3 decades. Accordingly, new discoveries tend to decrease on an annual base, and enhanced oil recovery (EOR) has the potential to reclassify unrecoverable and contingent reserves. EOR is viable because there are many available mature technologies, its implementation usually does not require drilling and completion cost, and most of the existing infrastructure can be used.
When I selected the EOR papers to highlight this year, I classified the papers into the categories of gas injection, chemical methods, thermal methods, conformance control, microbial EOR, carbonate-reservoir EOR, reservoir-problem-identification technologies, and novel EOR methods including low-salinity waterflooding, imbibition EOR, alkaline/surfactant/gas injection, and CO2-miscible combined with alkaline/surfactant/polymer injection. Not surprisingly, CO2 EOR and polymer floods have drawn great interest this last year because CO2 sequestration has been a great interest to the community and polymer flooding is a proven cost-effective chemical-EOR method. The published polymer papers cover mainly the topics of thermal-stability evaluation of different polymers, novel polymer-flooding modeling, polymer-rheology database, and the formation effects on polymer properties. The CO2 publications discussed mainly the feasibility-evaluation results of CO2-EOR projects in different oil fields worldwide.
An EOR project is not just a matter of injecting materials, with many factors affecting whether the project is successful. The design and implementation of an EOR project require a systematic integration from a multidisciplinary team. It is critically important to identify the problems of mature oil fields for a successful EOR project, and, thus, the papers to identify channels in mature oil fields were included in this EOR feature.
EOR Performance and Modeling additional reading available at OnePetro: www.onepetro.org
SPE 121460 • “Stability of Partially Hydrolyzed Polyacrylamides at Elevated Temperatures in the Absence of Divalent Cations” by R.S. Seright, SPE, New Mexico Institute of Mining and Technology, et al.
SPE 123971 • “Streamline-Based Simulation of Non-Newtonian-Polymer Flooding” by Abdulkareem M. AlSofi, SPE, Imperial College—London, et al.
SPE 123930 • “Identification and Characterization of High-Conductive Layers in Waterfloods” by C.S. Kabir, SPE, Hess, et al.
SPE 124930 • “Mechanistic Modeling of Emulsion Formation and Heat Transfer During the Steam-Assisted Gravity-Drainage (SAGD) Process” by Prince N. Azom, University of Texas at Austin, et al.
SPE 124946 • “Pore-Level Mechanics of Forced and Spontaneous Imbibition of Aqueous Surfactant Solutions in Fractured Porous Media” by Amar J. Alshehri, SPE, Stanford University, et al.
Industry Experience With CO2-Enhanced-Oil-Recovery Technology
Authors: Denney Dennis 
Published: February 2015

This article, written by Senior Technology Editor Dennis Denney, contains highlights of paper SPE 126446, ’Industry Experience With CO2-Enhanced-Oil-Recovery Technology,’ by R.E. Sweatman, SPE, Halliburton; M.E. Parker, SPE, ExxonMobil; and S.L. Crookshank, American Petroleum Institute, prepared for the 2009 SPE International Conference on CO2 Capture, Storage, and Utilization, San Diego, California, 2-4 November. The paper has not been peer reviewed.
This summary shows how the oil/gas industry has achieved success in engineering the process to capture, transport, and inject CO2 in enhanced-oil-recovery (EOR) projects. Some 37 years of safe and environmentally friendly large-scale operations, lessons learned, technical advancements, and millions of tons of CO2 injected demonstrate this success. With carbon capture and storage (CCS) being widely considered and with a few countries implementing commercial-scale CCS projects, technology transfer shares the experience of the oil/gas industry and the major contribution it can make as part of the solution for climate change.
Introduction
Since the first CO2-EOR patent was granted in 1952, the oil/gas industry has spent many tens of billions of dollars developing and implementing CO2-EOR technologies, asset development, and operational experience. As new sources of CO2 have become available, field-testing and demonstration or pilot-project activities have been conducted. These development and improvement efforts have been continuous since the first project in 1964. The first large-scale, commercial CO2-EOR project began operations in 1972 at the SACROC field in west Texas, which is still in operation. Many more projects have started since that time, and by 2008, the count reached 112 projects. Innovative, cost-effective materials, equipment, and methods continue to be developed and implemented, such as the introduction of real-time smart-well operations at SACROC.
CO2-EOR Technology for CCS Deployment. Underground geological storage of CO2 is a promising technology for reducing greenhouse-gas (GHG) emissions because much of the technology developed by the oil/gas industry that is associated with natural-gas processing and CO2 EOR can support the sound implementation of CCS. Large storage capacity exists in deep saline formations, depleted oil/gas reservoirs, and unmineable-coal seams. According to a report in 2005 by the Intergovernmental Panel on Climate Change, as much as 55% of a worldwide GHG-mitigation effort through 2100 could be achieved safely by use of CCS.
Reservoir-Management Practices in the Offshore Oil Fields of Saudi Arabia
Authors: Bybee Karen 
Published: February 2015

This article, written by Assistant Technology Editor Karen Bybee, contains highlights of paper OTC 20123, ’Reservoir-Management Practices in the Offshore Oil Fields of Saudi Arabia,’ by Hassan B. Al-Qahtani, SPE, Phillip Warren, SPE, Ali M. Al-Shahri, SPE, and Abdulrazzaq Al-Muhaish, Saudi Aramco, originally prepared for the 2009 Offshore Technology Conference, Houston, 4-7 May. The paper has not been peer reviewed.
Challenges associated in developing mature offshore fields of Saudi Arabia require the optimal integration of best reservoir-management practices. A variety of practices was implemented to achieve significant improvements in drilling and completing horizontal wells. Some of these challenges have been addressed with the installation of more than 200 inflow-control devices (ICDs) to minimize water-coning and gas-cusping affects. Economic development of these offshore projects has involved the implementation of 20 smart wells, in conjunction with intelligent-field monitoring.
Introduction
The developed offshore fields (M, Z, and S) of Saudi Arabia are in the Arabian Gulf and consist of sand-stones, siltstones, and shales with minor limestones and coals deposited in a complex, fluvial-dominated delta system. The main producing reservoirs consist of massive, clean highly permeable sandstone units interspersed with shales. The primary drive mechanisms for all three fields result from natural-aquifer influx with limited support from gas cap expansion in two fields.
Reservoir-Management Practices
The reservoir-management philosophy in the offshore environment is to maximize the economic recovery of oil and gas reserves while meeting production demand targets. In addition, the Saudi Aramco strategy offshore is to minimize water and gas production to avoid adverse effects on the facility infrastructure. Hence, best-in-class reservoir-management practices and innovative technologies were adopted in offshore fields to mitigate some of these concerns. The successful practices and technologies used to achieve significant improvements in drilling and completing horizontal wells in very complex reservoirs include
Measurement while drilling (MWD)/Gamma ray (GR)
Advanced geosteering/well placement
ICDs
Interval control valves (ICVs)
Smart dual-lateral wells
Smart in-situ gas lift systems
Permanent downhole monitoring systems (PDHMSs)
Elgin/Franklin: What Could Have Been Done Differently?
Authors: Bybee Karen 
Published: February 2015

This article, written by Assistant Technology Editor Karen Bybee, contains highlights of paper SPE 123681, ’Elgin/Franklin: What Could We Have Done Differently?,’ by Eric Festa, Total E&P UK, originally prepared for the 2009 SPE Offshore Europe Oil and Gas Conference and Exhibition, Aberdeen, 8-11 September. The paper has not been peer reviewed.
At the time of project sanction in 1997, Elgin/Franklin was the largest high-pressure/high-temperature (HP/HT) development in the world. It required innovation across the full range of operator activities. Eight years after production began, it is fair to say that Elgin/Franklin has not only achieved the aims of the initial project, it has clearly surpassed them. With hindsight, using this experience, combined with a decade of further progress in technology, some Elgin/Franklin-development features could have been optimized further.
Introduction
The Elgin and Franklin gas/condensate fields were discovered in 1991 and 1986, respectively, in the Central Graben area of the North Sea. The reservoirs are 5500 m deep and present abnormally high pressures (1100 bar), extreme temperatures (200°C), and significant levels of carbon dioxide and hydrogen sulfide. Facilities consist of two wellhead platforms, one normally unattended (Franklin) and the other located over the Elgin field. Glenelg and West Franklin are two HP/HT discoveries made after the initial development of Elgin/Franklin that were put on production in 2006 and 2007, respectively.
Initial Field Development
Field-Development Plan—1997. The development was based on 12 wells (seven on Elgin, five on Franklin) and included the recovery of two predrilled appraisal wells. Provision was included for a second Elgin wellhead platform, also bridge connectable to the process-utilities and quarters (PUQ) platform, to be installed later if warranted. The project included the installation of a normally unmanned wellhead platform on the Franklin field, with Franklin production transferred to the Elgin permanently manned PUQ platform by means of a multiphase interfield pipeline system (Fig. 1). The total estimated cost for the project represented a large investment, especially in the low hydrocarbon-price environment prevailing at the time.
The Elgin/Franklin project distinguished itself from other offshore installations in the UK continental shelf in that gas processing on the PUQ was designed to yield commercial-quality gas, satisfying both the Interconnector and National Transportation System specifications. On arrival at Elgin PUQ, the high temperature of the production demanded special cooling equipment. Titanium compact heat exchangers (CHEs) were selected because of their reduced weight compared to conventional shell and tube coolers.