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LOWELL, Mass.--(BUSINESS WIRE)--MACOM Technology Solutions Inc. (“MACOM”), today announced with Village Island that its MAEQ-23764 Bidirectional 12G-SDI Equalizer/Cable Driver has been selected for the recently announced VICO-4 TICO Serial Digital Interface (SDI) Converter. The MAEQ-23764 Bidirectional Equalizer/Cable Driver enables the VICO-4 system to configure the BNC ports to be either inputs or outputs, depending on the settings of the system. The VICO-4 uses Visually Lossless TICO compres


News Article | April 24, 2017
Site: www.businesswire.com

LAS VEGAS--(BUSINESS WIRE)--NHK and Village-Island have developed a new innovative system, called VICO-8, that makes possible to transport 8K 4:2:2 60p 10bits on a single 12G-SDI cable using intoPIX TICO compression technology. VICO-8 takes 8K video as 4x 12G-SDI input as compress by a factor of 4 to 1, in visually lossless quality, generating a single TICO 8K stream output mapped on a single 12G-SDI interface with a delay of few video lines, so less than 1msec. 8K 60p 4:2:2 (10bits) usually re


Weatherall G.,VICO | Halinda D.,VICO | Daungkaew S.,Schlumberger | Suriyanto O.,Schlumberger | And 2 more authors.
Proceedings of the Annual Offshore Technology Conference | Year: 2014

The coal bed methane (CBM) fields often showed wide variety of productivity ranges. Some wells were also drilled for both the CBM and the conventional oil & gas resources, hence adding the complexity of the well completion design. While designing for the optimal completion for both types of resources, the bounding shale layers properties become critical, especially when the coal layers are with lower permeability range and are to be fractured before production. The fracture treatment needs to be designed to be contained within the targeted zone, without bypassing the shale into the other layers (such as the water bearing sand). This is when the shale stress testing plays important role in providing the shale layers' stress parameters. The shale stress testing can be conducted with the dual packer module, which is part of Wireline Formation Tester (WFT) string. The tested shale zone is isolated with both packer elements, which is inflated with the wellbore fluid to create the isolation / sealing from the other zones. After packer inflation, the tested shale was injected with the wellbore fluid, or with fresh water specially carried down hole with the fluid chambers. The whole injection process is made efficient with the downhole pump module and the wireline cable conveyance, and multiple zones can be tested in one descent. After the injection, the pressure is allowed to fall off while the pressure and pressure derivative profiles are monitored. The data sets from two shale stress testing stations are presented as the case examples. The analysis of the data utilized the G-function plot, as well as square-root time plot. The output of the analysis included mainly initial breakdown pressure, closure pressure, fracture propagation pressure, and initial shut-in pressure. Permeability information could be extracted if the fall-off analysis showed clear radial flow regime. In one station, multiple cycles of injection - fall off process can be conducted to obtain better representative of the data sets. A reconciliation plot from all cycles in one station was then built to analyze the stress parameters. In larger scale, the measured parameters could be integrated into geomechanics study. Copyright 2014, Offshore Technology Conference.


News Article | December 2, 2016
Site: www.newsmaker.com.au

Wiseguyreports.Com Adds “Hospital Management System -Market Demand, Growth, Opportunities and analysis of Top Key Player Forecast to 2021” To Its Research Database This report studies Hospital Management System in Global market, especially in North America, Europe, China, Japan, Southeast Asia and India, focuses on top manufacturers in global market, with Production, price, revenue and market share for each manufacturer, covering Market Segment by Regions, this report splits Global into several key Regions, with production, consumption, revenue, market share and growth rate of Hospital Management System in these regions, from 2011 to 2021 (forecast), like North America Europe China Japan Southeast Asia India Split by product type, with production, revenue, price, market share and growth rate of each type, can be divided into Type I Type II Type III Split by application, this report focuses on consumption, market share and growth rate of Hospital Management System in each application, can be divided into Application 1 Application 2 Application 3 Global Hospital Management System Market Research Report 2016 1 Hospital Management System Market Overview 1.1 Product Overview and Scope of Hospital Management System 1.2 Hospital Management System Segment by Type 1.2.1 Global Production Market Share of Hospital Management System by Type in 2015 1.2.2 Type I 1.2.3 Type II 1.2.4 Type III 1.3 Hospital Management System Segment by Application 1.3.1 Hospital Management System Consumption Market Share by Application in 2015 1.3.2 Application 1 1.3.3 Application 2 1.3.4 Application 3 1.4 Hospital Management System Market by Region 1.4.1 North America Status and Prospect (2011-2021) 1.4.2 Europe Status and Prospect (2011-2021) 1.4.3 China Status and Prospect (2011-2021) 1.4.4 Japan Status and Prospect (2011-2021) 1.4.5 Southeast Asia Status and Prospect (2011-2021) 1.4.6 India Status and Prospect (2011-2021) 1.5 Global Market Size (Value) of Hospital Management System (2011-2021) 7 Global Hospital Management System Manufacturers Profiles/Analysis 7.1 Roche 7.1.1 Company Basic Information, Manufacturing Base and Its Competitors 7.1.2 Hospital Management System Product Type, Application and Specification 7.1.2.1 Type I 7.1.2.2 Type II 7.1.3 Roche Hospital Management System Production, Revenue, Price and Gross Margin (2015 and 2016) 7.1.4 Main Business/Business Overview 7.2 Konica Minolta 7.2.1 Company Basic Information, Manufacturing Base and Its Competitors 7.2.2 Hospital Management System Product Type, Application and Specification 7.2.2.1 Type I 7.2.2.2 Type II 7.2.3 Konica Minolta Hospital Management System Production, Revenue, Price and Gross Margin (2015 and 2016) 7.2.4 Main Business/Business Overview 7.3 Medex 7.3.1 Company Basic Information, Manufacturing Base and Its Competitors 7.3.2 Hospital Management System Product Type, Application and Specification 7.3.2.1 Type I 7.3.2.2 Type II 7.3.3 Medex Hospital Management System Production, Revenue, Price and Gross Margin (2015 and 2016) 7.3.4 Main Business/Business Overview 7.4 Nanjing Greatwall 7.4.1 Company Basic Information, Manufacturing Base and Its Competitors 7.4.2 Hospital Management System Product Type, Application and Specification 7.4.2.1 Type I 7.4.2.2 Type II 7.4.3 Nanjing Greatwall Hospital Management System Production, Revenue, Price and Gross Margin (2015 and 2016) 7.4.4 Main Business/Business Overview 7.5 SID MEDICAL TECHNOLOGY 7.5.1 Company Basic Information, Manufacturing Base and Its Competitors 7.5.2 Hospital Management System Product Type, Application and Specification 7.5.2.1 Type I 7.5.2.2 Type II 7.5.3 SID MEDICAL TECHNOLOGY Hospital Management System Production, Revenue, Price and Gross Margin (2015 and 2016) 7.5.4 Main Business/Business Overview 7.6 TOPSKY 7.6.1 Company Basic Information, Manufacturing Base and Its Competitors 7.6.2 Hospital Management System Product Type, Application and Specification 7.6.2.1 Type I 7.6.2.2 Type II 7.6.3 TOPSKY Hospital Management System Production, Revenue, Price and Gross Margin (2015 and 2016) 7.6.4 Main Business/Business Overview 7.7 eWorld Technology 7.7.1 Company Basic Information, Manufacturing Base and Its Competitors 7.7.2 Hospital Management System Product Type, Application and Specification 7.7.2.1 Type I 7.7.2.2 Type II 7.7.3 eWorld Technology Hospital Management System Production, Revenue, Price and Gross Margin (2015 and 2016) 7.7.4 Main Business/Business Overview 7.8 Xupeng Technology 7.8.1 Company Basic Information, Manufacturing Base and Its Competitors 7.8.2 Hospital Management System Product Type, Application and Specification 7.8.2.1 Type I 7.8.2.2 Type II 7.8.3 Xupeng Technology Hospital Management System Production, Revenue, Price and Gross Margin (2015 and 2016) 7.8.4 Main Business/Business Overview 7.9 VICO SOFTWARE 7.9.1 Company Basic Information, Manufacturing Base and Its Competitors 7.9.2 Hospital Management System Product Type, Application and Specification 7.9.2.1 Type I 7.9.2.2 Type II 7.9.3 VICO SOFTWARE Hospital Management System Production, Revenue, Price and Gross Margin (2015 and 2016) 7.9.4 Main Business/Business Overview 7.10 Future-med 7.10.1 Company Basic Information, Manufacturing Base and Its Competitors 7.10.2 Hospital Management System Product Type, Application and Specification 7.10.2.1 Type I 7.10.2.2 Type II 7.10.3 Future-med Hospital Management System Production, Revenue, Price and Gross Margin (2015 and 2016) 7.10.4 Main Business/Business Overview 7.11 Yahua 7.12 NewPoint 7.13 LANDWIND


Priambudi A.,VICO | Baraba R.N.,VICO | Tranggono N.W.,VICO | Aryanto B.,VICO
International Petroleum Technology Conference [IPTC] (Bangkok, Thailand, 2/7-9/2012) Proceedings | Year: 2011

The Badak Export Manifold (BEM) is a complex manifold to gather the entire gas delivery from upstream fields and to deliver hydrocarbons to liquefied natural gas (LNG) plant and to domestic commercial sites, manufacturing fertilizers and chemicals. Besides the function as gas processing facilities, the duties of the export manifold are to maintain pressure, distribute gas flow, implement off take logic during shut down and coordinate gas delivery. The BEM is the beginning of four main pipelines work in parallel configuration to allow flexibility of the gas delivery and to maintain gas composition within acceptable specification. The pressure stability and gas specification are the important aspects of the export manifold operations. In addition to richer gas composition, hilly terrains of the pipelines create liquid hold up (LHU) in the pipelines. The BEM takes an important part in the attempt to sweep liquid in the parallel mode by segregating gas flow into particular pipeline. Many efforts have been performed to improve export manifold operations. Included was the establishment of a clear operation guideline during normal and emergency situations, adjusting operations parameters to minimize unnecessary shut down, and installing additional equipment to allow remote operations of safety equipment within export manifold area. These days, almost all of the BEM parameters can be monitored remotely to support better operation.


Edy I.K.O.,VICO | Wicaksono D.N.,VICO | Saputra R.,VICO | Anantokusumo F.,VICO
Society of Petroleum Engineers - SPE/IATMI Asia Pacific Oil and Gas Conference and Exhibition, APOGCE 2015 | Year: 2015

VICO Indonesia is an Oil and Gas company which has operated mature fields located in the onshore part of East Kalimantan which has been on production for over 30 years. The fields are dominated by gas reservoirs with a much lower presence of oil reservoirs. Production mechanisms cover from natural depletion to weak and strong water drive, particularly in some of the shallow areas. Recent well completions include single and dual slimhole monobore. The field is a perfect combination of stratigraphic and structural traps with more than 4000 sandstone reservoirs where around 450 of those are oil reservoirs. The oil recovery factor for these reservoirs is in the range of 10-30%. Oil development in this fields performed using gas lift as the main artificial lift while several wells still flowing naturally. Coiled tubing gas lifted (CTGL) wells contributes to 60-80% of current oil production of 8000 BOPD. Totally, 50 CTGLs have been installed in VICO Indonesia where most of those considered successful. The main problem found related with initial operation after installation. Lesson learned has been summarized including the design and the procedure for initial operation. Coiled tubing gas lift design and troubleshooting are rarely found in literature. Thus, this paper presents the detail step by step design and how to troubleshoot the possible failure during early operation. This approach exhibits a real benefit to recover more untapped hydrocarbon with more aggressive program. Copyright 2015, Society of Petroleum Engineers.


Putro W.A.,VICO | Edy I.K.O.,VICO | Saputra R.,VICO | Anantokusumo F.,VICO
Society of Petroleum Engineers - SPE/IATMI Asia Pacific Oil and Gas Conference and Exhibition, APOGCE 2015 | Year: 2015

Mutiara is a mature field located in the onshore part of East Kalimantan which has been on production for over 30 years. The field is dominated by gas reservoirs with a much lower presence of oil reservoirs. Production mechanisms range from natural depletion to weak and strong water drive, particularly in some of the shallow areas. High decline rates are very common, which results in a very dynamic and challenging environment. The main artificial lift used in this field is gas lift. However, this method is not efficient for depleted or high water cut wells. Another issue is oil wells which located in remote areas which need high investment for surface facilities including gas lift line network and sufficient pressure to lift the oil up to the surface. Therefore, more and more wells will be idle without implementation of other artificial lift systems techniques. Several downhole pumping types have been assessed to tackle these issues such as Electric Submersible Pump (ESP), Progressive Cavity Pump (PCP), and Linear Rod Pump (LRP). Considering hilly swampy conditions of the field that requires more compact type of surface unit and flexible to match displacement rate to well capability as well declines. It is then decided to use LRP to unlock oil potential in idle wells. The first installation of LRP was on September 2014 in X-1 well, this well is the first well drilled in 1982. This installation succeeds on bringing back the well on production. The application of LRP provides opportunity to unlock oil potential from idle wells in this mature area thus maximizing reserve by gaining a few more hundreds barrels of oil per day during the first year. Copyright 2015, Society of Petroleum Engineers.


Andrianata S.,VICO | Susanto A.,VICO
Society of Petroleum Engineers - SPE/IATMI Asia Pacific Oil and Gas Conference and Exhibition, APOGCE 2015 | Year: 2015

Depletion of the reservoirs leads to a decrease in field production rate. Wells production rate continue to drop below the minimum critical velocity, at which point the liquid that was previously carried upward by the gas begins to fall back. The produced liquid accumulates in the well creating a static column of liquid, therefore creating a backpressure against formation pressure and reducing production until the well ceases production. Down hole Capillary Surfactant Injection (DCSI) is installed on the wells to overcome the liquid loading symptom by generating foam, thereby reducing the surface tension, lowering the fluid density, and lowering critical rate. This paper discusses the improvement to obtain higher success ratio of DCSI installation project on the observed field. Analysis and improvement is done to improve the success of DCSI installation through a comprehensive wells screening, continuity laboratory test, and field optimisation. The screening including the selection of liquid loaded wells & laboratory test (foam test, pH, and salinity test) were corrected with the actual temperature to obtain an accurate foam performance. Correlation is generated to correct the effect of foam build rate and decay rate against critical parameters. Validating well performances with the results of laboratory tests is conducted by continuously field optimisation. The laboratory test is significantly important to screen DCSI well candidate. Surfactant concentration, temperature, & condensate content are critical variables for foam build up and decay performances. Uncertainty variable and un-matching well performance previously not assessed can be reduced by these improvement steps, thus increasing the success ratio DCSI project. The improvement DCSI screening proposed is used as a reference to start the DCSI project to obtain higher success ratio. Copyright 2015, Society of Petroleum Engineers.


Suhendar A.D.,VICO | Kurniawan R.,VICO | Lizcano E.,VICO
Society of Petroleum Engineers - International Petroleum Technology Conference 2013, IPTC 2013: Challenging Technology and Economic Limits to Meet the Global Energy Demand | Year: 2013

VICO Indonesia operates the Sanga Sanga PSC in East Kalimantan which is on production since 1972. Reservoirs are mostly gas and depleted. Very Low Pressure compression "VLP" systems, which operate at 15-25 psig suction, are widely installed across all fields. As a result, flowing tubing head pressures in a large number of wells are in the order of 40 psi. Completion tubing sizes range from 2 3/8" to 4.5" with the majority being 3.5". Despite this, a large proportion of VICO's existing gas wells are subject to liquid loading, leading to premature abandonment of producing zones when the gas velocity in the tubing is lower than the critical velocity. This phenomenon is influenced by the tubing size, surface pressure and the amount of associated liquids produced with the gas. Historically, some temporary activities were carried out to overcome this problem. This included the reactivation of wells by flowing to flare and/or dropping foaming agents. The result of this type of "temporary" application was very variable and inconsistent. In an effort to continuously optimize the system and reduce the abandonment pressures, a large scope deliquification project was launched in 2006. The project included the application of capillary strings for down-hole chemical injection, plunger lifts, and wellhead compressors. This program was applied across all fields in VICO. The results were very positive in bringing back the production strings previously considered marginal or not producing. The field wide implementation program for both capillary string units and well head compressors was conceived to allow periodic relocation and optimization of the units and the system. As a result, all these deliquification techniques have now become a core element of the Base Production System. They continue to be optimized on a day to day basis and as a whole they are responsible for approximately 10% of the total production from VICO.


Hermawaty I.,VICO | Permana R.,VICO | Silitonga F.,British Petroleum | Wijanarko A.,VICO | Soenoro A.,VICO
Society of Petroleum Engineers - International Petroleum Technology Conference 2013, IPTC 2013: Challenging Technology and Economic Limits to Meet the Global Energy Demand | Year: 2013

VICO Indonesia is the operator of Sanga Sanga Production Sharing Contract (PSC) area in the onshore Mahakam Delta, East Kalimantan, Indonesia since 1968. Over 40 years, the PSC has produced more than 12 TSCF of gas through more than 800 wells to feed the Bontang LNG Plant and domestic market. One of the major fields in the contract area is the Badak Field, which has contributed more than 6 TSCF of gas production. Badak Field's reservoirs are the analog of the present day's Mahakam delta, and comprise of stacked distributary channel sands deposited in the deltaic environment draping on a four-way dip closure anticline. The shallower stratigraphic interval is dominated by fair to good quality upper delta plain, amalgamated channel sands, with a combination of water and depletion drive mechanism. The deeper stratigraphic intervals are dominated by fair to poor quality lower delta plain, more isolated distributary channel sands and mouth bar. The main reservoir drive mechanism is depletion drive. As the early development strategy of the Badak Field had been focused mainly on drilling the best reservoirs, those shallow reservoirs in the crestal area, the majority of these reservoirs are now depleted. In contrast, low permeability deeper reservoirs with relatively higher reservoir pressure, still contain significant remaining resources. VICO's depletion challenge is to balance between increasing the recovery from the deeper intervals, whilst continue optimizing the recovery from shallow intervals. An Integrated subsurface study has been conducted to understand the geological description of the reservoirs, ultimately to unlock the reserves of the deeper low permeability intervals. Several development options have been carefully evaluated, which lead to the implementation of new technologies to optimize recovery, including cluster wells, horizontal wells, and hydraulic fracturing. The results of the implementation of the development strategy and technology have been outstanding. This has helped sustain the Badak Field's decline rate at around 25% annually compared to a 45% natural decline. In 2011, the gas production was successfully maintained at 75 MMSCFD or 3 times the base line of the "do nothing" case prediction, with more than 55 BSCF of reserves progressed. This paper describes the successful implementation of integrated development study, which proved to be an effective process to ensure optimum reservoir management of low perm reservoirs of a mature asset. Copyright © (2013) by the Society of Petroleum Engineers.

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