bluuebunny/crossref_metadata_2025_split huggingface dataset:
A Novel Approach to Determine Minimum Riser Top Tension Setting and Comparison with Traditional Methodology – Analytical Case Study
Authors: Thomas Reena 
Published: October 2015

Abstract
As the development of offshore hydrocarbon reserves extends into greater water depths, the drilling riser requirements and limits have become more onerous due to harsh environmental conditions and uncertainties involved in response prediction. The dynamic response of the vessel to environmental conditions can significantly impact the response of the riser tensioner systems. In the case of deep-water drilling applications, as per API RP 16Q, the riser string must always be in positive effective tension. However, in the case of modern riser tensioner systems, which have non-linear stiffness and damping characteristics, the effective tension in the riser can vary substantially as the tensioner strokes in response to vessel heave. In order to accurately predict the loads on the riser using finite element analysis, the tensioner system has to be accurately modeled in great detail.
This paper presents a comparative analysis of direct acting and wireline tensioner system responses for a range of environments using a top tension setting calculated as per API RP 16Q. The detailed tensioner model used for the analysis has been validated against manufacturer performance data for existing in-service tensioner systems and includes the individual hydraulic and pneumatic components of the tensioner system. A non-linear structural FE analysis tool is used to model the detailed tensioner model as part of a drilling riser string.
The analysis results show that there are large percentage variations in the effective tension at a given point along the riser. The dynamic tension variation displays an increasing trend as the heave velocity increases. An alternate method to calculate the top tension setting and it's impact on the minimum effective tension along the riser string is discussed herein.
Synthesis and Evaluation of A Macromolecular Viscosity Reducer for Venezuela Heavy Oil
Authors: Bin Ding , Xiangfei Geng , Lipeng He , Baoliang Peng , Jianhui Luo 
Published: October 2015

Abstract
Orinoco heavy oil belt in Venezuela is a world-famous heavy oil belt, and difficult to develop due to the high viscosity of crude oil. In order to reduce the viscosity, a water-soluble macromolecular viscosity reducer (commercial name: CVR-V) for MPE3 block is designed and prepared. It is synthesized via copolymerization, and plays an important role as emulsifier in forming O/W emulsion. The experimental results demonstrate that CVR-V show extremely superior initial viscosity reduction effect and the O/W emulsion stabilized by CVR-V exhibits excellent static and dynamic stability. The optimum condition for viscosity reduction is obtained: with the ratio of 10:3 (oil to water), and 0.1 ~ 0.2% of viscosity reducer, the initial viscosity reduction rate reaches 99.8% approximately and the apparent viscosity is less than 100 mPa·s. Meanwhile, excellent static and dynamic stability are proved, i.e. the apparent viscosity of O/W emulsion is still less than 500 mPa·s after standing for 60d for static stability tests, and is also less than 200 mPa·s in rotation 7d later by vertical loop for dynamic stability tests. Laboratory experimental results demonstrate that the fluidity of Venezuela's ultra heavy oil can be greatly improved by CVR-V, and CVR-V exhibits strong potential in development of Venezuela heavy oil.
Use of Cluster Analysis to Improve Representative Model Selection: A Case Study
Authors: Baker Mark 
Published: October 2015

Abstract
An accurate representation of the range of possible subsurface outcomes is critical for effective appraisal and development of petroleum resources. The infinite number of possible subsurface realisations is typically represented by a small number of representative reservoir models that are then used for more detailed analysis. This study investigated the applicability of cluster analysis to deterministic model selection for an undeveloped gas reservoir, using the results of response surface models. Two cluster analysis techniques were compared against standard model selection methods. Cluster analysis was found to perform better than traditional methods of model selection in generating robust, representative and varied models for scenario analysis and development planning. Generalised sensitivity analysis, GSA, was performed to complement the model selection process.
Deepwater Facility Integrity Management: A State-of-the-Art Review
Authors: Allen Eric 
Published: October 2015

Abstract
The offshore oil and gas industry recognizes and agrees that there are too many instances of premature failures leading to loss of life, environmental impacts, reputation damage, increased downtime, and production losses. In response to this situation, there has been rapid growth in integrity management related research and development, however it has become difficult to keep track of all of this activity. The purpose of this state-of-the-art review paper is to summarize key findings and provide a comprehensive list of pertinent literature in the field of deepwater facilities integrity management. Focus is given to the latest information on integrity management systems, regulations, standards and recommend practices, and current industry challenges. The goal of this paper is to consolidate and provide the most updated information regarding integrity management, in order to assist those individuals and companies that are new to this field. Several of the referenced documents are available to the public via the World Wide Web. The references are provided for information only, and do not represent a comprehensive list of applicable standards, recommend practices, or regulations.
Managing Integrity and HSE in a 40 Years Old Installation
Authors: Aryaguna A. , Razy F. , Hadipamenang S. , Haekal T. , Pranyoto P. , Sudjarwadi S. 
Published: October 2015

Abstract
TOTAL E&P Indonésie (TEPI) is the biggest gas producer in Indonesia, who also produces oil. At the time this paper is written, TEPI is operating six Production Sites, two Logistic Bases, seven Drilling Rigs, hundreds of Floating Vessels and thousands of Oil & Gas wells.
Central Processing Area (CPA) is a site that produces oil with some free gas from 555 deltaic multilayer sand reservoirs of Handil field. The site was built 40 years ago with its peak production around 200,000 BPD of oil in 1977. Today CPA produces on average 16,000 B/D of oil and 30 MMsfcd of gas. From total 694 well strings, only about 20% of it is actively flowing; these well strings are spread over 65 clusters. Most of the oil wells are artificially lifted by pump or gas lift compressors.
Facilities were added and adapted along with the needs, such as High and Low Pressure gas compressors and Gas Lift Compression unit. Several Enhanced Oil Recovery (EOR) projects had been tried, such as gas injection, air injection, and water injection. Currently the only artificial lift remaining is gas lift, and the EOR remain is water injection; the rests are stopped and modified.
Nowadays, the main challenges of this mature field are integrity and HSE. Old design, obsolescence, modification of existing facility, and integrating with new technology generates several risks. Along with the maturity, leaks and potential leaks increase over time. The issues are corrosion, surface cracks, seepages, fugitive emission, obsolete equipment, increasing sand production, etc. Furthermore, several disused equipment also become another threat.
This paper will discuss how CPA, a 40 years old Oil & Gas Production Installation, manages its Integrity and HSE. It will explain the challenges, good initiatives, and room for improvements. The topics will include Risk assessment & Identification, Inspection strategy, Integrity, Maintenance, Preservations, Work Permit implementation, Emergency exercise, etc.
Paradigm Shift From Traditional to Modern Drilling Using Simple Management Tool
Authors: Azwar Noezran , Abdila Sayid F. , Fadil M. 
Published: October 2015

Abstract
Objectives/Scope: Reports from a NOC under Production Sharing Contract with SKK Migas show that MDT success ratio conducted is only 40–50% between years 2012 to 2013. High frequency of failures happened in 12 ¼" hole. The objectives of the research are to find out source of the problem and the solution. The scope of the research is MDT procedure conducted in years 2012 – 2013.
Methods, Procedures, Process: Research starts with investigation of years 2012 to 2013 MDT failures. The results then categorized as equipment and tools related, procedures related, and human error. The results show most of failures root-caused by insufficient procedure. Further investigation using interview with engineers and reports examining conducted on the existing procedure. Investigation shows the NOC not conducting proper management of change process to include MDT procedure since they believe existing procedure is adequate for additional MDT work. The research then exercises new drilling procedure using management of change and lean sigma approach. New drilling and MDT procedure then applied to year 2014 campaign.
Results, Observations, Conclusions: In late 2013, SKK Migas enforced the NOC to apply proper drilling procedure for MDT. The NOC used management of change and lean sigma process to design new procedure and included any additional works required. The NOC also used heuristic approach to adapt the lithology character of subsurface formations and aquifers specifically since there was coal layer beneath. The NOC also considered any lesson learn from adjacent well and field. Drilling campaign in 2014 for the field consists of 10 drilling with MDT. New procedure was applied and close monitoring was performed. Nine of ten drilling works with MDT were successfully performed without major incidents. The wells are still producing and showing good production performance. The NOC also successfully uses MDT results from nine wells to predict field performance and planning 2015 drilling campaign.
Novel/Additive Information: Management tools such as management of change process and lean sigma has been applied in many fields of work nowadays. The practices assure that any additional works or changes will be adopted properly and in a new and lean procedure or design. This paper shows radical success ratio increase when those management tools are applied especially for traditional-fashioned NOCs.
Improving Efficiencies of Short Duration Projects During Turnarounds: A Case Study on Innovative Breathing Air Solutions
Authors: Schoeib Sameh , Dowd Darrell , Daher Elie 
Published: October 2015

Abstract
A frequent challenge during facility shutdowns and turnarounds is the congestion of work areas. As a result, carrying out short-duration tasks such as blinding with powering pneumatic tools take much longer time due to equipment transport and set up the process. To respond to this challenge, a portable breathing air delivery unit was designed with a narrow footprint to allow quick and easy deployment even in constricted work areas.
The portable breathing air unit provides ten man-hours of breathing air and can support two users. It has a separate air tool port to power pneumatic tools. A backflow preventer ensures that air tool cannot contaminate the breathing air supply. As a safety measure, the air tool supply shuts down at 1000 psi, leaving the worker with approximately two man-hours of breathing air. To ensure that personnel have the required safety equipment and the ability to complete their assigned jobs, the unit is equipped with a platform to transport required gear to remote work areas.
The portable breathing air unit was recently put to the test by a Gas to Liquids company during its emergency facility turnaround. This is a case study for the use of such system capable of providing both breathing air and power tools in constricted work areas. During a turnaround for example, to remove a set of flange bolts from a pipe, the entire operation may take 10 minutes, but the actual operation of the air wrench may only take two minutes of that time. However, actual job tickets indicate that a 10-minute job takes a minimum of 30 minutes to one hour to complete due to the long process of deploying safety gears, breathing air systems and a separate pneumatic power source. By utilizing this portable breathing air delivery system with a dual purpose, activities such as blinding can be done more efficiently while ensuring personnel safety.
This case study discusses the significance of this innovation in improving efficiencies during turnarounds.
Digital Oilfield Down Under: Implementation of an Integrated Production Monitoring and Management System for the Maari Field, Taranaki, New Zealand
Authors: Marron A. J. , Milner M. , O'Hagan A. , Biniwale S. S. , Trivedi R. , Simpson T. , Tran A. C. 
Published: October 2015

Abstract
The Maari oil field, the first OMV operated offshore oil field development, has showcased OMV's impressive technical skills. Following the completion of a field re-development drilling campaign in August 2015, the well configuration currently consists of 10 producers and 1 water injector (with the option to convert a producer into a water injector in the future). Electric Submersible Pumps (ESPs) are installed on all 10 producing wells to provide lift of reservoir fluids to surface. A SCADA system and associated Production Historian Database (PHD) was included in order to capture the high frequency data for well & reservoir surveillance and daily production optimisation of the field. However, there were many challenges in utilising this live data stream from the offshore facility. In particular, it was vital to continuously and effectively monitor and optimise ESP performance in order to improve run life, reduce downtime and ultimately increase production. An integrated decision support system was therefore required for real-time data collection, production monitoring, ESP health check and KPI analysis for proactive decision making and limiting the number of manual processes involved.
This paper describes how these challenges were overcome by creating an integrated workflow and aligning the existing system architecture in order to meet the business needs. The system is based on full workflow automation, and has been deployed for data acquisition, validation and analysis by optimising the components of integrated asset management. The system includes an integrated framework connected to various live data sources with different time increments, allowing data aggregation to a reliable intra-day hub. Automated job scheduling has also been built in with a decision support dashboard setup for production analysis and ESP performance monitoring. Based on historical trends, an optimum operating envelope was defined and automatic rules were configured for anomaly detection.
The system has provided standardized data access throughout the asset team, streamlining their entire process and resulting in improved efficiency, which has optimised the engineers time for core operational activities. With a secure and automated workflow, and the ability for multiple users to work simultaneously, the system has minimised their downtime, thus improving overall productivity. Utilizing the live data feed for updating of simulation models has allowed quicker comparisons of numerical predictions with analytical forecasts, hence helping to streamline the overall reservoir management of the field. The system has not only assisted the team in meeting their production reporting deadlines, but has also alleviated bottlenecks in their decision-making processes helping to boost overall asset productivity.
Samarang Integrated Operations (IO) – Dynamic Production Management - A Hybrid Approach from Steady State to Transient Modeling
Authors: Izzami M. Hafez , Ahmad Zul Izzi , Sepulveda Willem , Salim Muzahidin Muhamed , Wong Lee Hin , Som M. Kasim , Biniwale Shripad , Rodriguez Nelson , Kumar Ram , Wilson Matthew , Eradajaye Iroro 
Published: October 2015

Abstract
Samarang is a 35-year-old offshore oilfield in Malaysia, operated by PETRONAS Carigali Sdn Bhd (PCSB). Samarang Redevelopment Project was kicked-off in 2010. Integrated Operations (IO) was planned as an Asset Management Decision Support solution by implementing a real time production, reservoir and process surveillance system. Samarang field was the first field selected for end-to-end asset management IO project. The main objective of IO implementation is to focus at the whole asset operation rather than working in silos. The overall asset optimization is achieved through the levels of monitoring and surveillance, diagnosis, optimization and operations transformation.
IO Implementation involves identification of various intelligent asset decision processes referred as workflows in various reservoir, production, and operation domains such as Flow Assurance, Well Performance, Artificial Lift, Production and Facility Planning and Enhanced Oil Recovery (EOR) Optimization. Optimization in Samarang covers a wide spectrum of scenarios from Artificial Lift (Gas Lift, Electric Submersible Pump), separation process, reservoir sweep (Waterflood, GASWAG EOR scheme). The main business driver is to enhance production and improve reserve recovery in order to ramp up the production of Samarang field.
Hybrid Steady-State and Transient-State Total Asset Optimization is designed for implementation through Steady-State model based simulation while the Transient-State model continuously predicts short term transient production effects, as a result asset team can better manage the short term production upset to ensure optimization target is achieved. The transient normally manifests as "Flow Assurance" events such as slugging and surges and these manifestations are to be predicted through transient-state modeling and hence, allow corrective action to be taken through Tri-Node Collaborative Working Environment (CWE).
The hybrid modeling techniques treat the asset as a whole unit instead of isolated silos, simulating the complex interactions between reservoir, production networks and process facilities where decision taken on the production network will propagate the impact to reservoir performance and vice versa.
Rate Transient Analysis in Hydraulic Fractured Tight Gas Reservoir
Authors: Joo Hyeonseog , Ki Seil 
Published: October 2015

Abstract
In order to evaluate development plan of unconventional tight gas reservoir in production stage, Rate Transient Analysis techniques can be utilized to get estimates of OGIP, EUR, SRV, and relevant information, which are based on boundary-dominant flow analysis. In this study, various RTA techniques (Flowing Material Balance, Type Curve Matching, Square Root Time Plot, and Analytical Model Analysis) are carried out to get these estimates and validate results to each others.
Under the condition of the field in this study, about 2.3 years' production data, flow-rate and flowing well-head pressure, micro-seismic, loggings, and relevant data are utilized for analysis of production performance and estimate of OGIP, EUR, and SRV. In the target well of study, boundary dominant flows start after initial 8 months. The various RTA techniques (Flowing Material Balance, Type Curve Matching, and Square Root Time Plot) show consistency of the time for initial boundary dominant flow, and the reliable analytical model analysis result validate estimate of OGIP, EUR, and SRV from the various RTA techniques.
Even though we have reliable well production estimation, there must be uncertainties for pressure depending SRV. By changing the analysis point after those periods, time-depending changes of OGIP, EUR, and SRV can be traced. This trend can provide guidelines for reservoir simulation study and its history matching scheme. In this study, the integrated analysis of RTA and simulation and its results are provided.
Analysis of Miscibility of High Sour Component (H2S and CO2) Content Gas Flooding Under Abnormal Reservoir Pressure
Authors: Xu Anzhu , Mu Longxin , Zhao Liangdong , Wang Chenggang , Zhang Chengshuo 
Published: October 2015

Abstract
The main factors of influencing the recovery efficiency of gas drive are miscible degree and gas channeling in carbonate reservoirs with double porosity. The components of injection gas significantly influence the miscibility of enriched gas with the same important function of the minimum miscibility pressure, reservoir pressure. High hydrogen sulphide content (H2S) and carbon dioxide (CO2) content in reservoir production, abnormally high reservoir pressure (&gt;70MPa) and specifics of field position (offshore) lead to great challenge for this kind of oil field development. Produced sour gas as an injection fluid without desulphurisation to reduce investment cost and therefore decrease negative environmental impact is proposed a good way to solution the oil filed development problem. Some produced gas samples were analyzed in laboratory. Detailed PVT results on miscibility of reservoir oil and injection gas showed a good correlation of the majority of the parameters, and the established compositional model calculations illustrated that when the content of H2S and CO2 become higher, the injection gas were more easily fully solved in the oil and residual oil saturation could be reduced to the minimum level. Another important aspect solved during the reservoir modeling in this study was definition the changes of minimum injection gas and reservoir fluid miscibility pressure with the variety of the content of the sour gas. During the injection gas combined drive, miscible displacement could take place horizontally or vertically depending on the reservoir configuration. This work illuminated vertical displacement generally occurs in widely spread steeply dipping structures. The efficiency of gas re-injection into the upper part of the reservoir and production of oil from the base for vertical displacement is low due to the flow barrier which limits vertical gas advancement.