bluuebunny/crossref_metadata_2025_split huggingface dataset:
Ocorrência fúngica em goiaba ‘paluma’ submetida a impacto e transportada em dois tipos de embalagens
Authors: Freire Maciel Dos Santos , Cerzar Márcia Aparecida , Araújo Railene Hérica Carlos Rocha , Souza Francisco De Assis de , Lima Tiago Augusto Cardoso de 
Published: October 2017

<p>No Nordeste, é comum a utilização de embalagens inadequadas para transporte de frutos,acarretando injúrias que servem como porta de entrada de patógenos. Objetivou-se avaliar a incidência de podridão, severidade e ocorrência fúngica em goiaba ‘Paluma’ transportada em dois tipos de embalagens. Frutos foram colhidos na Fazenda Mocó, Aparecida, Paraíba, no estádio de maturação “de vez”, e submetidos aos tratamentos por impacto através de queda à altura de 85cm sob piso industrial, caracterizando os tratamentos: T<sub>1</sub>, frutos submetidos a impacto, embalagem em caixa plástica de polietileno; T<sub>2</sub>, frutos submetidos a impacto, embalagem em caixa de papelão; T<sub>3, </sub>frutos sem impacto, embalagem em caixa plástica de polietileno; T<sub>4,</sub> frutos sem impacto, embalagem em caixa de papelão; T<sub>5,</sub> testemunha, frutos sem injúria mecânica. As amostras foram transportados por 45 km, até o Laboratório de Fitopatologia da Universidade Federal de Campina Grande, Campus Pombal. Os resultados de severidade mostraram que o tratamento T<sub>1</sub> difere significativamente dos demais. Os tratamentos T<sub>1</sub> e T<sub>2</sub> apresentaram maior incidência de frutos com podridões. A maior ocorrência de fungos foi verificada nos tratamentos com caixa plástica, mostrando que este tipo de embalagem favorece a incidência fúngica.</p><p><strong><em>Fungal occurrence in guava 'paluma' submitted to impact and transported in two types of packaging</em></strong></p><p><strong>Abstract: </strong>In the Northeast it is common the use of inadequate packaging for fruit transportation, causing injuries that serve as pathogen gateway. This study aimed to evaluate the incidence of rot, fungal severity and occurrence in guava 'Paluma' transported in two types of packaging. Fruits were collected at farm Mocó, Aparecida – PB during maturation "of time," and subjected to treatment by impact through the fall height of 85 cm under industrial floor, featuring treatments: T1, fruits subjected to impact, packaging in plastic polyethylene box; T2, fruits subjected to impact, packing in cardboard box; T3, fruit without impact, packaging in plastic polyethylene box; T4, fruit without impact, packing in cardboard box; T5, witness, fruit without mechanical injury. These were carried by 45 km, to the Phytopathology Laboratory of CCTA. The results show that the severity of the treatment T1 differs significantly from the others. The T1 and T2 had a higher incidence of decayed fruits.</p>
Evaluation of the First Cycle of Steam Stimulation in North Kuwait Heavy Oil Thermal Pilots
Authors: Al-Ali Yacob , Wang Guojuan , Al-Mula Yousef , Hussein Mahmoud , Choudhary Pradeep , Ahmed Fatma 
Published: October 2017

Abstract
There are two ongoing steamflood pilots with inverted five-spot, 5-acre and 10-acre spacing patterns in North Kuwait heavy oil field. KOC determined that performing two or three Cycle Steam Stimulation (CSS) cycles followed by steamflood is required to achieve the production target from a multi-layer reservoir with two vertically separated heavy oil zones.
A previous reservoir simulation study identified two possible completion strategies. One completion strategy for simultaneous steaming in the 5-acre spacing pattern and the other completion strategy for steaming one zone at a time in the 10-acre well spacing pattern.
In this paper, we discuss for the two pilots, operational and monitoring challenges and the substantial difference in the performance after first CSS cycle for the two well completion strategies.
The Steamflood pilots are currently at the pre-flood stage and the first cycle of the Cyclic Steam Stimulation (CSS) has been finalized. A comprehensive reservoir and well surveillance program is being conducted to monitor and gather data necessary to better understand the reservoir and well performance in the pilots.
One of the goals of the pilots is to use the acquired reservoir understanding to determine a completion strategy for commercial development of the field from two options identified in the reservoir simulation study. This paper presents insights on the difference in the performance with the two well completion strategies.
The first CSS cycle in the wells with 10-acre spacing and the completion strategy for steaming one zone at a time demonstrated relatively better performance compared to the wells in the 5-acre pilot with a completion strategy for simultaneous steaming where more challenges were observed.
The reservoir properties and field surveillance data were used to explain this performance difference for the two well completion strategies after first cycle of CSS.
The recommendations and conclusions in this paper are based on actual field data in a multi-layered heavy oil reservoir after the first CSS cycle. Future papers will present the results after further CSS cycles and steam flooding.
Well and Inflow Performance Relationship for Heavy Oil Reservoir under Heating Treatment
Authors: Hakiki F. , Aditya A. , Ulitha D. T. , Shidqi M. , Adi W. S. , Wibowo K. H. , Barus M. 
Published: October 2017

Abstract
Well and Inflow Performance Relationship, termed TPR and IPR, respectively have been the unfailing methods to predict well performance. It is further to determine the schemes on optimising production. The main intention of the study is to explore TPR and IPR under heating treatment for heavy oil well. Klamono is a mature field which mostly has depleted wells, it produces heavy oil within 18.5 °API (&gt;0.95 g/cc oil density), and therefore, artificial lifting method is necessary. Sucker Road Pump (SRP) and Electrical Submersible Pump (ESP) are the most deployed artificial lifting method in this reservoir. To boost the heavy oil production, the application of Electric Downhole Heater (EDH) in Well KLO-X1 is being studied. Whole Klamono's production is more than 100,000 blpd within 97-99% water cut. By installing EDH, oil viscosity is decreased hence oil mobility ratio will play a role to decrease water cut. EDH is installed together with the tubing joint to simplify its application in the wellbore. The study shows that EDH application can elevate fluid (mixed oil and brine) temperature. Oil viscosity confirms a reduction from 68 to 46 cP. The gross well production is up to 12.2 bopd due optimising its outflow performance and reducing 97.5 to 96.9% water cut. The field data gives an incremental of 4.9 bopd. The computational results only show an attainment of net oil production up to 8.3 bopd (2 bopd incremental). The EDH works to lessen both density and viscosity as we hypothesised for the mechanism of thermally induced oil production improvement. The evaluation study on its economics aspect exhibits good result that is 1.4 USD/bbl additional profit margin according to field data despite the challenging annual rig rent cost. Following the field data, the expected net income through analytical model revealed that this project is financially promising.
Gas-Assisted Gravity Drainage GAGD Huff n Puff Application for Fractured Basement Reservoir - Case Study
Authors: Dinh H. K. , Le N. V. , Peter M. G. , Nguyen V. T. , Dang T. S. , Nguyen V. Q. , Hoang N. D. , Truong T. A. , Tran H. M. , Nguyen K. B. 
Published: October 2017

Abstract
Gas injection methods such as Continuous Gas Injection, Water Alternating Gas and conventional Gas-Assisted Gravity Drainage (GAGD) have been widely used to improve/enhance oil recovery for conventional oil reservoirs. However, applications to naturally fractured basement reservoirs are still limited. This paper will introduce a case study of a new and effective GAGD method conducted in a Huff ‘n’ Puff fashion to improve oil recovery for a fractured basement reservoir in Cuu Long Basin, offshore Vietnam.
A GAGD pilot, which consists of 4 cycles, was conducted in which dry gas was periodically injected into an existing production well in an isolated area. It was expected that as the injected gas rose to the top to form a gas zone, it would push the Gas Oil Contact (GOC) downwards and might also push the Water Oil Contact (WOC) to the lower part of the producer or even away from the bottom of its wellbore. Before commencing the 4 cycles, gas injection, asphalting and reservoir simulation studies were conducted. In addition, a thorough forward plan was carefully devised before each cycle to determine possible effects of important operating parameters to the final outcome of that cycle.
From the results of the 4 cycles, it could be concluded that the gas injection volume is well correlated with cumulative water-free oil production, a parameter which indicates the effectiveness of the method in terms of the gravity-drainage mechanism. It could also be found that the final incremental oil gain of each cycle depended upon, not only, the gas injection volume, but also other important factors such as gas injection, shut-in time… suggesting that a non-linear optimization exercise is necessary to make the whole pilot economically successful.
The success of the GAGD pilot proves that it could be a simple and effective Improved Oil Recovery (IOR) method for fractured basement reservoirs. That can be a foundation for further application of the method to other reservoirs in the Cuu Long Basin.
First Open Hole Horizontal Near HP/HT Critical Sour Gas Wells Completion in Indonesia: Lesson Learned from BD Field Development Project in Kujung Formation
Authors: Nurdin M. S. , Etuhoko M. O. , McKen D. R. , Lian J.. , Syapari A.. , Nuryadi H.. , Fadil M.. , Utomo P. P. 
Published: October 2017

AbstractBD is a near high pressure-high temperature (HPHT) critical sour gas field located in offshore Madura Strait in water depth of 152 ft. An exploration and appraisal well were drilled in 1987 and 1992 respectively, targeting BD reef at depth of 10,676ft SSTVD. Both well test results confirmed the limestone formation has characteristic of 305°F and 8,105 psi, with 5,000 ppm of H2S and 5.5% of CO2 content.Four (4) development wells including three (3) horizontal and one (1) vertical well, were drilled to drain the reserves from BD field. The project was expected to deliver 120 MMSCFD of gas and 6,000 bpd of condensate for a period of 15 years production from BD field. Design, equipment and material to complete the well need to meet the target and be selected based on industry guidance and the environment to ensure the integrity of the well during the production time.Completion for BD wells adapts multiple tie-back concept to provide consistent large flow area and big bore advantages, providing flexibility for future well intervention. It consists of 3 (three) main assemblies and was designed based on series of load cases to predict the completion reliability to withstand the load during the life of the well. During the installation, the assemblies were run in different batches and fluid environment.Despite the challenges encountered during the preparation and installation, all wells were successfully completed and cleaned up safely without any incident. The completion could exceed the initial production target set by the reservoir engineering team.This paper will discuss about the completion process from the first near HPHT sour field development project in Indonesia. It describes the design process, preparation and installation of the BD completion especially in the horizontal well. Challenges, basis of design, material selection, lessons learned and optimization taken to safely deliver the completion are also covered in this paper.
Low Field Cryoporometry NMR for Mesopores Distribution in Shale
Authors: Jin Xu , Wang Xiaoqi , Liu Xiaodan , Jiao Hang , Sun Liang , Su Ling , Bi Lina , Chen Yu 
Published: October 2017

Abstract
A large number of micro–nanopores constitute the main reservoir space of shale oil and gas reservoirs. To evaluate a reservoir pore throat system's structure, it is of great significance to quantitatively characterize the pore distribution. There are two commonly used methods for characterizing the pore structure: mercury intrusion and gas adsorption analysis. The mercury intrusion method is to determine the pore size distribution by measuring the amount of mercury in the pores under different external pressure. The detection range of this method is pores with diameters of 3 nm–400 μm, and the optimal detection range is pores with diameters of 100 nm–100 μm. The gas adsorption analysis method is to measure the adsorption amount of nitrogen and other gases at the liquid nitrogen temperature. the optimal detection range of this method is pores with diameters of 0.4–100 nm. Because of the complex structure of porous materials, the results of different experimental methods are inconsistent, and the pore structure information provided by a single method is limited. Since different porous solid materials have different chemical and physical properties and different pore diameter range, it is necessary to select experimental methods for the target material. This paper introduces a new method of measuring pore distribution, which is a Low Field Cryoporometry NMR method. Based on the principle of the nanometer-confined effect, this method can measure mesoporous distribution of different porous materials and shale. The logarithmic pore diameter distribution and the pore diameter distribution histogram indicate that the shale sample's pore volume is mainly comprised of pores with a diameter of 80–500 nm, which is consistent with the pore statistical results of the SEM analysis. The porous size distribution (PSD) was obtained by Croporometry NMR (NMRC) for shale samples, which was compared with that from the measurements by Brunauer-Emmett-Teller Method (BET).
This method enlarges the scope of the classical gas adsorption method, then can be used to study pore diameters from 10 nanometers to micron size. Furthermore, it provides an important reference to the study of the pore structure of shale oil and gas reservoirs.
Thixotropic Conformance Sealant for Horizontal or Highly Deviated Wellbores
Authors: Vasquez Julio , Eoff Larry , Lewis Chris 
Published: October 2017

Abstract
Excessive undesired fluid production, either water or gas, is a widespread problem withinthe oil and gas industry that can detrimentally affect the profitability of hydrocarbon-producing reservoirs, thus limiting their economic life. A wide variety of chemical technologies have been implemented throughoutthe years for controlling unwanted fluid production with some degree of success. However, when these types of treatments are applied to horizontal or highly deviated wells, placement control becomes a critical factor. Depending on fluid density differences and wellbore deviation, conventional conformance treatments can slump/rise along horizontal sections, compromising the placement accuracy and overall treatment success. This paper discusses the development and application of a thixotropic conformance sealant (TCS) system specifically designed to help control unwanted fluid production in horizontal or highly deviated wellbores. The stress-dependent (thixotropic) rheological properties of the TCS system provides rapid viscosity increase afterplacement, allowing the treatment to remain in place until in-situ crosslinking occurs at a predicted time, helping provide a competent and precise seal across the targeted area.
The TCS system is based on an organic-crosslinked polymer gel system combined with optimized rheological modifiers. It provides a predictable and controllable crosslinking time to obtain adequate placement. It can be placed into the wellbore by bullheading or using a coiled tubing (CT) unit. Once it is strategically placed into the zone to be shut off, in-situ gelation is activated by the reservoir temperature, plugging the permeability of the treated area, thereby limiting undesired fluid flow. The TCS system can be formulated to allow penetration into the formation matrix or to bridge off at the formation face for limited leakoff, to help provide a controlled and shallow penetration at the formation face. Laboratory data ispresentedas well as preliminary results of field applications.
Other thanthixotropic cement slurries, the TCS system is the first conformance technology tailored to horizontal applications within the oil and gas industry, helping reduce excessive undesired fluid production while extending the economic life of the wellbore and reservoir. The TCS system is applicable to different completion types such as openhole, slotted liners, openhole gravel-packs (OHGPs), and casedhole gravel-packs (CHGPs), among others.
Technical Integrity Management System
Authors: Hasanah Uswatun , Wibisono Sigit 
Published: October 2017

Abstract
In Total E&P Indonesie, Technical Integrity Management System (TIMS) is the means of ensuring that the people, system, processes and resources which deliver technical integrity are in place, in use and fit for purpose over the whole lifecycle of the assets, with purpose to avoid major accidents whilst meeting the production objectives. The system covers 4 key elements: plant, people, process and performance.
Total E&P Indonesie TIMS is applicable to all operational activities and assets under TEPI custodianship, from early conceptual studies, engineering, construction, and operations up to sites restitution. Adherence to this Integrity Management System is applicable for all TEPI personnel, contractors, sub-contractors, suppliers, service companies or any other organizations or personnel performing work in connection with TEPI activities and/or assets.
The paper will provide sharing experiences of Total E&P Indonesie in implementing Technical Integrity Management System with the feedback from the operational entities as the risk owners.
The objectives of Technical Integrity Management System are managed through following steps: –Set up integrity policy and procedures: issuance of company procedures.–Set up integrity management network: appointment of Discipline Integrity Engineers (DIC) and Specific Elements Lead Engineers.–Set up and monitor Integrity Performance: Sites, Entities and Affiliate Integrity Dashboard reporting and monitoring.–Major Integrity Threats (MIT) workflow: Identification of potential integrity threats, threat's risk evaluation, mitigation and remedial action definition, MIT declaration, MIT actions follow up, MIT closed out.–Manage Safety and Environmental Critical Element (SECE) based on Technological Risk Assessment (TRA) study result: SECE identification, alignment, implementation, reporting and follow up.–Management review and endorsement: management review through specific meeting.–Audit and verification: cross functional entities verification.
Main keys contributing to the success of the prevention of Major Risk in oil and gas operation is the active participation from all of the involved entities with excellent cooperation and coordination.
TIMS has been implemented for the last 5 years in Total E&P Indonesie. Improvement effort is continuously identified and implemented through the years.
Guidelines for the Environmental Monitoring of Oil and Gas Industry in Italy: Seismic, Ground Deformation and Reservoir Pressure Measurements
Authors: Macini P. , Mesini E. N. , Antoncecchi I. , Terlizzese F. 
Published: October 2017

Abstract
Today, HSE issues, environmental conservation and social acceptance are paramount in all industrial sectors. In particular, the social and environmental impact of E&P industry must be wisely evaluated and monitored. Following this direction, the Italian Oil & Gas Safety Authority (DGS-UNMIG, a Directorate General of the Ministry of Economic Development) issued a new set of monitoring guidelines for future licensing and E&P operations in Italy. After the seismic sequence of May 2012 in Northern Italy, a public discussion pointed out that these earthquakes could have been related to possible "anthropogenic" causes, i.e., a seismic activity induced or triggered by underground fluids withdrawal. For this reason, the Italian Department of Civil Protection appointed an independent international scientific commission to evaluate all available geoscience data to shed light on this hypotesis. In particular, three production fields, located near the epicenters of the seismic sequence, were closely examined: 1) a geothermal field; 2) an underground natural gas storage field; 3) a mature oilfield with reinjection. According to the conclusions of the above International Commission, the National Oil & Gas Safety Authority issued a new document of monitoring guidelines. In particular, future E&P operations in Italy must be complemented by properly designed monitoring networks aimed at controlling the: a) seismic activity; b) ground deformation; c) reservoir pressure. The monitoring networks must be implemented as soon as practicable when licensing is granted, in order to evaluate prior local seismicity and ground deformation with a sufficient accuracy. Moreover, monitored data must be made available to the safety Authorities, and thorough informative actions to residents and stakeholders must be properly carried out. The paper illustrates the above guidelines, the recent agreements signed with the Emilia-Romagna Regional Government and the present monitoring performed at selected Italian pilot test sites, according to the indications contained in the abovementioned guidelines.
Shallow Reservoir Development in Mature Field - From Hazard to Resources
Authors: Setiawan T.. , Putra A.. , Az-Zariat A.. , Rinjani K.. , Brahmantio R.. , Herawati S.. 
Published: October 2017

Abstract
TUNU is a gas condensate field situated in the swamp environment at the edge of the Mahakam Delta, East Kalimantan – Indonesia. Hydrocarbons are accumulated in multi-layer reservoirs deposited within a deltaic environment. The field can be divided into two intervals which are Tunu Shallow Zone (TSZ) (between 600 and 2,200 mSS – typically unconsolidated and strong aquifer support) and Tunu Main Zone (TMZ) (between 2,200 and 5,000 mSS).
Since the field start up in 1990, it has delivered 9 Tcf of gas production. At the beginning, the field's first development was focusing on TMZproduction, where the gas reservoir at TSZ was only considered as hazard for drilling. Through time, TMZ is more and more depleted; hence development of TSZ is the new focus.
TSZ dedicated development started in 2007 by drilling two horizontal wells, each targeting individual channel followed by drilling of four deviated twin wells. Given the excellent result, new campaign of TSZ development was kicked off. Since then, more than 185 TSZ wells have been drilled contributing to 40% of around 700 MMScfd of total field production. This is resulted from improvement on selection of new wells target, cost effective well architecture and efficient reservoir management.
The first seismic survey targeting TSZ was performed in 2009 and since then TSZ development relied on detailed interpretation of seismic anomalies. Performing detailed interpretation is a major challenge on designing economical wells. This difficulty has been accentuated by recent downturn of gas price; hence having full field geobody inventory is becoming crucial. A geomodel was therefore built to have an exhaustive view of TSZ resources.
Optimization in selecting well architecture is also deemed necessary. Tubing-less completion with Chemical Sand consolidation (SCON) was assessed and shown that it can give more cost effective completion compare to gravel pack completion. Drilling cost could be reduced up to 30 % by using tubing-less completion with SCON.
Production optimization can be achieved by carefully implement the efficient reservoir management technique, e.g. maximize the number of completed reservoir zones without risk to safety and production, selection of best reservoir zone for first production, and implementation of flowline debottlenecking to accommodate hepta-mingle wells.