bluuebunny/crossref_metadata_2025_split huggingface dataset:
Evaluasi Adopsi Inovasi Feed Additive Herbal untuk Ternak Ayam Pedaging
Authors: Sari Ayu Intan 
Published: October 2016

<p><em>The purpose of this research is to evaluate technically and economical adoption of herbal feed additive innovation for broiler. </em><em>This research was conducted from August to October 2008, in the broiler farm at Karanganyar, Sragen, and Boyolali by using research based method of descriptive analysis. The respondents of the research were 34 farmers selected by using purposive convenience sampling</em><em>. </em><em>Evaluation technical adoption of herbal feed additive innovation, was analyzes base on the respondent’s answer to questionnaire which draw a process adoption of innovation, consist of the first reason of farmer apply innovation, process receiving innovation and the difficulties and in apply innovation. The result of research shows based on technical evaluation result there differences adoption innovation process on adopter category early and late, it is first reason receive innovation where on early adopter category because on broiler production higher (52,94%), while the first reason for late adopter category in receive innovation because to save production cost (47,06%). The result also shows that early adopter category of farmers (58,82%) not found difficulties in apply innovation feed additive, while in late category adopter (52,94%) . Found difficulties in apply innovation feed additive. Base on economic evaluation value, the income of broilers farm without using feed additive herbal at scale <span style="text-decoration: underline;">&gt;</span> 8.000 broiler Rp 2.392,18 per broiler, scale 3001– 8.000 broilers Rp 1.910,54 per broiler, and the income at scale <span style="text-decoration: underline;">&lt;</span> 3000 broilers Rp 1.616,59 per broiler. Income of broilers farm with using feed additive herbal base on scale <span style="text-decoration: underline;">&gt;</span> 8.000 broilers Rp 2.557,19 per broiler, scale 3001- 8000 broilers Rp 1.767,15 per broiler. The conclusion from this research are different evaluation score technical adoption innovation feed additive herbal at the early and late adopter category, it is on the first reason in receive innovation where the early adopter category because of the broilers productivity higher, while late adopter category in receive innovation because the save the production cost. Base on economic evaluation result, there is increase income received by farmers after using innovation feed additive herbal and more scale broilers farm, so the advantage which get also bigger.</em></p><p><em> </em></p><strong><em>Key words</em></strong><em>: Technical evaluation, economic evaluation, adoption invation, herbal feed additive</em>
Improved Framework for Measuring the Magnitude and Impact of Biases in Project Evaluation
Authors: Alarfaj M. K. , McVay D. A. 
Published: October 2016

Abstract
Several authors over several decades (Capen 1976; Brashear et al. 2001; Rose 2004) have observed that industry performance has been consistently below expectations. While this is painfully obvious during the current industry downturn, available evidence suggests that even when the industry is profitable, e.g., during the decade prior to the most recent downturn, it still performs substantially below its expectations and its potential (Nandurdikar 2014). Many attribute this underperformance to cognitive biases in project evaluation, resulting in poor project selection and valuation. McVay and Dossary (2014) presented a simplified framework to estimate the cost of underestimating uncertainty. They demonstrated that chronic overconfidence and optimism (estimated distributions of project value too narrow and shifted positively), common in industry, produce substantial disappointment (difference between estimated and realized portfolio values), also common in industry.
In this work, we generalized their framework to include full estimated distributions (e.g., normal or lognormal), instead of the truncated distributions they employed. In addition, we extended their framework to model underconfidence (estimated distributions too wide), and demonstrate that underconfidence is just as detrimental to portfolio performance as overconfidence. Decision error will be minimized and portfolio value will be maximized when there is no bias in project estimation—i.e., neither overconfidence nor underconfidence and neither optimism nor pessimism.
Using either framework, we demonstrate that operators can quantitatively measure biases—overconfidence, underconfidence, optimism and pessimism—from lookbacks (comparing actual performance to probabilistic forecasts) and generation of calibration plots. Once aware of the direction and magnitude of biases, operators have means for eliminating these biases in subsequent forecasts through a combination of internal correction of uncertainty assessments, via training or ongoing feedback, and external correction of forecasts using measurements of bias from calibration results.
Integrated Multi-Disciplinary Approaches to Predict Fluid Contacts in a Partially Appraised Field - A Case Study of Yoko Field in Niger Delta
Authors: Adedoyin Orekoya , Eteobong Etokakpan , Suleiman Ahmed , Keme Bomo , Basak Prahlad , Amogu Daniel , Longe Victor , Ejiuwa Nworie , Remmy Ugboaja , George Kakayor , Kachi Onyeagoro 
Published: October 2016

Abstract
The need for the estimation or evaluation Original Oil Water Contact (OOWC) prior to reservoir development is very pertinent to appropriate well placement within a reservoir. Oil and gas water contacts are determined via various sources including but not limited to Petrophysical logs, RCI data, Reservoir Simulation, Fault Seal Analysis (FSA), Quantitative Interpretation and Hydrocarbon Column Analogues. This paper focuses on an integrated approach of predicting OOWC using some of the methodologies highlighted above.
The study explores the feasibility of further oil development in the Yoko field to grow production and increase reservoir ultimate recovery. Three wells have been drilled so far in the field and none encountered OOWC. Three (3) key reservoirs account for about 69% of the total field hydrocarbon resource but with significant uncertainty in fluid contacts column (about 132ft) and wide static and recoverable volume range.
An effective and commercially viable field development plan is premised on the reduction of contact uncertainty. In order to narrow the contact uncertainty, multidisciplinary approaches has been used and they include (a) Petrophysical Logs (b) Structural Spill Point (c) Analogue oil column studies from adjacent fields (d) Fault Seal Analysis (FSA) to determine maximum column in the reservoir (e) Quantitative Interpretation (QI) and (f) Dynamic simulation.
The analogue oil column from neighbouring field was used to benchmark the possible oil column for Yoko field. FSA which relies on the sealing capacity of the faults due to the amount of mechanical mixing from fault throws was also considered. The upper and lower limits of the fluid contacts were estimated from acoustic impedance amplitude plotted against depth. The reservoir dynamic models was also history-matched (7 years of production history) to calibrate and ascertain the limits of the possible contacts for the reservoirs.
The result of the evaluation is a significantly reduced volumetric uncertainty range. In one of the reservoir, there was a progressive reduction in fluid column uncertainty from 232 ft to 90 ft. In general 55 - 85% reduction of the initial uncertainty was achieved. This reduced range enabled a commercially viable Development Plan for the field.
Cemented and Cased Hole Multistage Stimulation Technology Development and Field Wide Implementation in a North Sea Chalk Oilfield
Authors: Mehus C. , Sørheim T. , Lønning P. , Koløy T. R. 
Published: October 2016

Abstract
In close cooperation with a major international operating company, the service company specialising in completion Sliding Sleeve technology has developed a completion system that facilitates efficient Multistage Stimulation, and allows production management and re-fracing/stimulation of individual zones. The field wide implementation of the system has yielded a step change for the operator in terms of operational efficiencies, production management and re-fracing/intervention capabilities. This paper will present the successful technology implementation on a giant North Sea chalk oilfield.
A collaborative approach was taken, with close dialogue between the operating company and the service company, in defining the system requirements for the desired completion and stimulation methodology. Design criteria for tools were developed, validation testing and product qualification of the individual components followed by field trials were conducted. Throughout the process, a detailed focus on job preparation, execution and integration with the overall well construction and stimulation process was essential in ensuring the successful technology implementation.
This paper will discuss the technology development and implementation project resulting in two reservoir completion systems being installed in more than 27 wells in the same field. One of the systems is a cemented multi entry ball drop system, the other is a cased hole single entry ball drop system.
The process of technology implementation with focus on various case histories is presented. The installation and operational sequences and challenges that have been encountered will also be discussed. The paper will provide insight into how these systems provide unique benefits to the operator during the following phases of the wells life: Completion - Sleeve design and qualification grade significantly reduces completion steps and cost for the operator.Stimulation - stimulation efficiency provides dramatically reduced opex compared to alternative methods.Production Management - the system has built in features that allow management of unwanted production by cost efficient intervention method.Re-Stimulation - controlled re-stimulation of individual zones is possible.
This paper will present the collaborative development and field wide implementation of cemented and uncemented Multistage Stimulation Technology that has rapidly gained operator acceptance and realized significant cost savings to the operator. Both the technology and methodology used and the results achieved should be of interest to the petroleum industry.
Perforation and Rig Flowback Highlights for the Gorgon Field Development Wells
Authors: Morrison AK , Beinke JP 
Published: October 2016

AbstractThe Gorgon LNG Project is one of the world's largest natural gas projects and the biggest single resource development in Australia's history. Once online, gas from 18 subsea producers across the Gorgon and Jansz-Io fields will deliver a combined 15.6 MTPA of liquefied natural gas (LNG) to domestic and international export markets via three LNG trains situated on Western Australia's Barrow Island (Fig. 1).From May through to November of 2014 the eight Gorgon foundation wells were successfully perforated, intercepting between three and seven commingled zones and gross intervals of up to 500 metres (m) per well. Perforation was conducted on wire-line with a total of 69 perforating runs made during the campaign. Directly following perforation, all eight wells were unloaded and cleaned-up by flowing back each at 80 MMscf/d for 12 – 24 hours to the Ocean America mobile offshore drilling unit (MODU).This paper will contrast the detailed perforating and flowback plan, developed with numerous likely contingencies, against the actual results of the operation where a number of the planned and also some unplanned contingencies were enacted.The agreed perforating basis of design called for multiple wireline runs of 4.5" diameter guns with lengths of up to 80 feet, using a specially designed high strength gas blocked cable to accommodate well conditions. A top-down perforating strategy was planned to maximise the dynamic underbalance effect and optimise the clean-out of perforation tunnels. A number of operational events on the first well prompted a switch to a bottom-up perforating methodology that in turn had a number of significant knock-on effects which will be described in full.The flowback operation represented a once in a field-life opportunity to acquire commingled well samples and provide validation of several critical reservoir, fluid and well properties such as gas contaminant levels, water of condensation, compositional variation, vertical lift performance, sand production and the presence of formation water. As flowback operations progressed a feedback loop was incorporated, ensuring that the program was optimised as data gathered reduced uncertainty levels. Arguably the most commercially significant contribution, was the assurance that the deliverability of the eight Gorgon field producers was sufficient to meet their commitment to the Gorgon project.Ultimately, though sharing the susccessful case study of the Gorgon Perforating and Flowback campaign, this paper emphasises the value in developing appropriate contingencies in advance of operation commencement as well as retaining program flexibility to enable changes to be made at short notice throughout the operational campaign.
The Research and Application about Aluminate Cement Slurry in Heavy Oil Thermal Well
Authors: Li Zaoyuan , Cheng Xiaowei , Zhang Mingliang , Wu Xingru , Wu Shuang , Wu Dongkui , Xiao Yunfeng 
Published: October 2016

Abstract
According to the requirements of rapid setting at low temperatures and long-term performance during high-temperature production on cementing for heavy oil thermal recovery wells, this study proposes the application of aluminate cement to cementing of heavy oil thermal recovery wells. Against the background of operation conditions in Liaohe Oilfield, the strength decline mechanism of the conventional silicate cement stone added silica sand were evaluated by simulating the high-low temperature circulating humid environment that the cement sheath of the heavy oil thermal recovery well faced with. Then, through laboratory experiments, the research compounded a kind of mineral clinker based on aluminate cement, prepared fluid loss agent J73S and retarder SR compatible with aluminate cement and designed a new-type thermostable aluminate cement slurry system with an applicable density range of 1.70g/cm3~1.90g/cm3 and temperature range of 30°~80°. Moreover, the hydration product and the thermostable mechanism of the modified aluminate cement slurry were analyzed through this simulation. According to the results, with the crystalline transforming at high temperatures, the strength of conventional silicate cement with silica sand substantially declines under the condition of multi-cycle high-low temperature circulation, therefore it cannot satisfy the cementing requirement of thermal recovery wells effectively. The thermostable aluminate cement slurry system features excellent engineering performance: the slurry density difference is lower than 0.02 g/cm3, the fluid loss is less than 50 ml, the thickening time is adjustable from 60 min to 300 min, the 24h strength is up to 14 MPa, and the compressive strength of cement slurry can still reach 25 MPa after two rounds of high-temperature testing. In addition, the SiO2 in the additives massively participate in the hydration reaction, endowing the modified aluminate cement slurry with favorable thermostable performance and long term stability. The application of the cement slurry system to cementing for heavy oil thermal recovery wells of Liaohe Oilfield exhibits a smooth operation process and excellent cementing quality, so it can efficiently satisfy the cementing operation requirement of heavy oil thermal recovery wells efficiently.
What Vacuum Insulated Tubings Or Vacuum Insulated Casings Bring To Thermal Wells
Authors: Damour J. , Johannson D. 
Published: October 2016

Abstract
Thermal wells were widely developed with the expansion of thermal enhanced oil recovery processes like SAGD, CSS or steamflood. These high temperature processes brought new challenges to the well design in term of well integrity and well performance. The use of vacuum insulated tubing (VIT) or vacuum insulated casing (VIC) has significant benefits on the well completion by two main aspects: mitigate the effect of high temperature on some part of the completion and reduce the heat loss from the injected steam.
This paper describes both design and economic considerations that lead to the selection of VIT or VIC for the completion of thermal wells. Vacuum insulated tubing design makes significant progress driven by its strength and weaknesses. VIC was developed as an alternate solution for some specific completion. The main well integrity failure modes are reviewed: casing expansion and resulting loads, cement integrity under thermal cycling, annular pressure build-up. A thermal well modeling providing casing and tubing temperature assesses the solution brought by VIT (or VIC) to avoid a well failure. On the well performance side, the heat loss will be presented for different VIT product to measure the impact on the efficiency of the process and the economic aspect.
The results shared in this paper are some of the parameters considered during thermal well design: temperature on the casing, tubing and heat loss. Knowing these parameters, the well integrity can be studied and the overall efficiency of the process estimated. Some simple cases between different completion using VIT or different VIT products are run as a comparison. More specifically, the thermal model will show how a non-thermal well can be converted to steam injection by using the proper VIT.
The wide range of thermal performance of VIT is to be understood when it comes to select the proper product for thermal well application.
Investigation Into the Use of Commercial Sands and Fines to Replicate Oil Sands for Large-Scale Sand Control Testing
Authors: Mahmoudi Mahdi , Fattahpour Vahidoddin , Nouri Alireza , Rasoul Saad , Yao Ting , Baudet Beatrice Anne , Leitch Michael , Soroush Mohammad 
Published: October 2016

Abstract
This paper presents the characterization of oil sands from the McMurray Formation. The main objective of this paper is to investigate the possibility of replicating the oil sands by the mixtures of commercial sands and fines for large-scale testing. There is a growing interest in large-scale evaluation testing for sand control devices that require considerable amounts of representative oil sands materials. However, natural representative oil sands samples are usually not available or are limited in quantity. Therefore, replicating the oil sands is essential for such tests.
Twenty-three oil sands samples were collected from two wells in the McMurray Formation and cleaned using the Soxhlet extraction technique. The cleaned samples were examined using the image analysis technique and Scanning Electron Microscope (SEM) imaging to study their Particle Size Distribution (PSD), shape factors, mineralogy, and texture. Similar analysis was performed on eleven series of commercial sands to compare their shape, mineralogy, and texture with those of oil sands. Particle Size Distribution of 10 commercial fines was also analyzed with a particle sizer to cover the required fine/clay part of the duplicated samples. Direct shear and 1D consolidation were performed to compare the mechanical properties of the oil sands samples and the duplicated mixtures of commercial sands and fines.
The shape factors of the oil sand and the selected commercial sand samples are in close agreement. In addition to the common average/cumulative shape factor measurements, this paper also presents the variation of shape factors within each sample for different grain sizes. The results show the same sand shape characteristics among all oil sand samples as well as the tested commercial sands. Further, XRD results indicate a similar mineralogy for the commercial sands and the oil sands samples. The SEM images show random changes in the surface texture of both oil sands and commercial sands with no observable trends. We were able to use commercial sands and fines mixture with similar grain shape properties to duplicate the PSD of the oil sand samples. Direct shear and 1D consolidation testing of the oil sands and samples made of commercial sands and fines show similar consolidation and frictional properties for both the duplicated mixture and cleaned oil sands for the same compaction level (porosities).
This paper provides a procedure for duplicating the oil sands with commercial sands and fines. It also provides detailed information on the mineralogy, texture, and the variation of the shape characteristics for oil sands from the McMurray Formation.
New Product Line Evaluation Method Saves Cost and Time on Qualifying Connections for Thermal Wells
Authors: Nowinka Jaroslaw , Dall'Acqua Daniel 
Published: October 2016

Abstract
Integrity of high-temperature post-yield (HTPY) wells demands use of casing connections that demonstrate suitable structural strength, sealability and galling resistance. Since 2010, Thermal Well Casing Connection Evaluation Protocol (TWCCEP, published as ISO 12835) has been used by operators and connection manufacturers to assess connection performance under representative field conditions. While technically rigorous, TWCCEP programs are costly and time-consuming, and full-scope TWCCEP evaluations on multiple size/weight/material combinations are challenging to achieve.
This paper describes a product line evaluation (PLE) approach that enables effective qualification of several members of a connection family for HTPY applications with substantial savings of effort, cost and time. Some PLE strategies were used in the past for conventional stress-based-design applications, but not for strain-based-design applications – until recently, when a new HTPY PLE approach was proposed via an industry-sponsored project. This new HTPY PLE method relies on existence of a Reference Connection that has been qualified with a prior evaluation and/or field use. Another member of the same family (Candidate Connection) is then qualified based on existing data for the Reference Connection, and comparative evaluations of the Reference and Candidate Connections.
The paper illustrates basic HTPY PLE concepts, and analytical-experimental tools and processes used for the comparative evaluations. The HTPY PLE method incorporates several assessment steps, which PLE users select according to their field application severity, risk tolerance, and desired level of confidence in the assessment results. The paper emphasizes significance of design and manufacturing variables that are relevant for the HTPY PLE method, some of which are not commonly monitored by connection users – such as circumferential non-uniformity (seal waviness). In a case study example, the paper shows how the HTPY PLE can be used to qualify a connection needed for an optimized well completion, and the resultant cost-time savings. Upon validation, the HTPY PLE method is expected to enhance effectiveness of thermal well integrity and reduce connection failure potential.