bluuebunny/crossref_metadata_2025_split huggingface dataset:
Petroleum Trapping Mechanism Attributed to Facies and Deformation History of Kujung-1 Miocene Carbonate in Ujung Pangkah East Java
Authors: Murtani Anom Seto , Irfree Baharianto , Setyohadi Setyohadi , Dwiperkasa Dhea Wachju 
Published: October 2015

Abstract
Intense compression in northeast Java and facies complexity in carbonates has triggered the complexity of petroleum trapping mechanism. Different fluid contact level between Ujung Pangkah and Sidayu field indicates something has happened during the migration. The shelf edge line that act as the southern trap of Ujung Pangkah that was interpreted in a relatively straight east-west direction can be develop into some other sensible interpretation.
Ujung Pangkah is one of the oil and gas producing fields in the East Java Basin. The field is located in the southwestern part of the JS-1 Ridge. This area is bounded to the east by the Central Deep grabens, Tuban trough the west Kening Deep to the south. The northern margin is east-west highs and lows structure that was formed due to trans-tensional faults initiated by the left lateral strike-slip faulting.
Geochemical analysis shows the hydrocarbon of Ujung Pangkah and Sidayu are from the same kitchen area. Based on the distance and maturity, Kening Trough is believed to be the main hydrocarbon kitchen of the Ujung Pangkah and Sidayu. As the spill point between Sidayu and Ujung Pangkah kept going deeper, this spill point evolved to be a preventer of the hydrocarbon migration to Sidayu while the petroleum kept charging into Ujung Pangkah from the south.
New ways to look at the trap mechanism has lead into some step-out prospects that give advantages to this field to stay productive.
How Powerful Material Balance Analysis Method for Predicting Gas Flooding Performance
Authors: Sutoyo H. R. , Ariadji T. , Aziz P. A. , Mahendra M. L. 
Published: October 2015

Abstract
Gas Flooding is one of the reservoir production management methods which commonly used in the petroleum industry in order to improve oil recoveries and maintaining reservoir pressure. This study discusses two methods in analyzing gas flooding, i.e., material balance analysis and reservoir simulation methods. The objective is to examine the ability and advantages of material balance method with respect to reservoir simulation.
The studied field has three productive zones which consist of two light oil zones and one dry gas zone. Gas flooding scenario was conducted in one light oil reservoir and was modeled using both material balance and reservoir simulation methods to predict reservoir performance for about 14 years and the results were compared to investigate the effect of gas injection. The material balance method employs production, PVT, pressure data, and averaged properties of geological model for a single tank model. On the other hand, the reservoir simulation method uses a compositional model to investigate in detail the effect of injected gas to reservoir fluid behavior and the oil recovery
The examinations indicate that the material balance analysis method shows the advantages of a requiring much less data, but could give reasonably accurate results. Furthermore, the application of material balance analysis in gas flooding could be used for gas injection rate optimization for a very short time manner and could assist for further development of reservoir simulation. For future development, material balance analysis could be used to analyze gas flooding scenario to save time and cost rather than reservoir simulation which takes longer time.
The Production Data Management Platform for Reservoir Management and Optimisation: A Case Study
Authors: Tran T. V. , Hoang H. M. , Tran N. H. , Giang T. H. , Pham K. N. 
Published: October 2015

Abstract
Bien Dong POC (BDPOC) operates two gas condensate fields located offshore Vietnam and exports the produced gas to the Nam Con Son pipeline. Along with the evolution of advanced technology, real time data incorporated into flexible services architecture has contributed significantly in increasing efficiency, accelerating production, reducing downtime and regulatory events (Naser and Awaji 2011). The Production Data Management Platform (PDMS) was implemented before the first commercial gas, allowing the BDPOC to be readily prepared for first gas, enjoy the benefits of tracking all the production and operation parameters since day one for operational purposes and also enable the ability to understand better reservoir dynamics at very early stage of the production (Tran et al. 2014).
With this data converted into information, BDPOC can safely operate the current and future oil and gas assets, accurately report to authorities and stakeholders, perform asset surveillance, diagnosis and ultimately optimize production amid operational constraints.
As the PDMS provides foundation layer for managing the production for the two fields, and it's helping today to improve the timely decision making process through the use of accuracy, and validated data; this effect is impacting positively by allowing BDPOC to adjust production rates to deliver contractual terms of demanded production in a matter of a few hours.
The goal of this paper is to present the architecture and highlight the advantages and benefits that can be drawn from the utilization of the Platform Solution as key foundation block today and how it fits the Roadmap to Asset Optimization in the future for BDPOC.
This case study illustrates the challenges of acquiring, storing, and production information. The main components are deployed for the PDMS along with the up-to-date technologies that can effectively be used to meet these challenges. The Platform Solution allows BDPOC to have reliable production information at their fingertips.
Abnormal Temperature Gradient in North Kuwait; A Case Study
Authors: Millán Arcia Einstein , Cesar Velasquez , Saffar Ali Al 
Published: October 2015

Abstract
A consistent abnormal tendency of the temperature profile has been observed in two neighboring fields belonging to the North Kuwait Asset (NKA), showing lower temperatures in the lowermost structure, and higher temperatures in the uppermost structure within the same Middle Marrat formation. The observed temperature behavior is contrary to what is expected, as uppermost formations typically tend to be cooler than lowermost formations, as dictated by a normal geothermal gradient response.
Formation temperature readings have been crosschecked using 3 independent sources, each showing the same uncharacteristic trend. This phenomenon of temperature gradient inversion has been correlated against fractional fluid composition and geothermal properties of the formation.
Based on available seismic & geological information, there are signs of the existence of overlying "gas clouds", linked to the presence of "Chimneys", which may act as heat source. Massive water bearing shale layers which may act as a natural heat storage chambers have also been detected supporting the presence of abnormal geothermal gradients. The immediate effect of this anomaly has been linked to fluid redistribution. Gravity segregation as the main driver for fluid redistribution has been discarded because the MM formation in one of the fields is highly fractured and its matrix is mostly oil wet, implying a negligible effect of gravity over capillary forces.
The objective of work reported herein is to describe the implications of this abnormal geothermal gradient on fluid thermodynamic gradation and redistribution with depth. Based on actual well test, seismic and geological data, the combined effect of column height and temperature equilibrium on fluid composition was assessed by applying the Equation of State (EOS), while allowing small changes in depth, temperature and pressure gradients.
Discrete fluid composition was determined using available PVT software, and two existing and validated laboratory generated PVT data sets. This in turn was used to reproduce the variation of fluid column with depth that corresponds with the observed abnormal temperature gradient.
Online Bioremediation for Wastesolid and Wastewater at Drilling Waste Management
Authors: Lesto A. , Kusumo P. 
Published: October 2015

Abstract
Hazardous materials that are produced from drilling operation is a sensitive case. It needs more efforts to manage waste material. Online Bioremediation technology is one technology to reduce potential hazardous materials. Bioremediation is eco-friendly technology to remediation hazardous material. It will reduce the hazardous value at waste drilling material through degradation process. Adding Online Bioremediation system will give more protection to environment from potential hazardous materials. Pollutants or contaminants on wastesolid and wastewater are main problems in petroleoum industry. Bioremediation will reduces waste generated during drilling activities to acceptable environmental levels. Usually, Bioremediation process will be treated on land treatment and land farming, and this process will take times and cost. Online Bioremediation technology is in situ bioremediation process. This technology will work in parallel with drilling waste management system. Online Bioremediation will process wastesolid and wastewater in site of drilling projects.
Mechanistic Modeling of Gel Microsphere Surfactant Displacement for Enhanced Oil Recovery after Polymer Flooding
Authors: Chen Xianchao , Feng Qihong , Sepehrnoori Kamy , Goudarzi Ali , Bai Baojun 
Published: October 2015

Abstract
The gel microsphere is an effective profile control agent to mitigate water-channeling problems in mature oil reservoirs. Recently the gel microsphere combined with high effective surfactant is proposed to enhance oil recovery after polymer flooding. Although some experimental and field studies have demonstrated the synergistic effect of polymer/gel microsphere/surfactant, there are no relevant models that can handle the combined effects. Hence, mechanistic modeling is needed for EOR after polymer flooding.
In this work, the transport properties of gel microspheres are combined with polymer and surfactant model. In the coupled model, the migration mechanisms and retention controlling factors of gel microspheres are analyzed according to lab tests, which resulted in the development of the filtration migration equation and dynamic permeability model. The interaction mechanisms between gel microsphere and polymer/surfactant are mathematically described according to experiments, in which the surfactant model is implemented based on a model implemented in a commercial simulator. The coupled model is numerically solved by an implicit-pressure, explicit-compositions (IMPEC) method. The surfactant module is verified with a commercial simulator. The robustness of the coupled model is also validated with a core flooding case to reproduce injection pressure. Furthermore, the coupled model provides an efficient method for predicting gel microsphere-surfactant flooding performance, which helps to determine the technical feasibility of the project.
The interaction between gel microsphere and surfactant is modeled for EOR performance prediction in this work. The newly presented model will help to improve our understanding of the gel microsphere/surfactant flooding.
The Effects of Test Interval on Safety Instrumented Function (SIF) According to Safety Integrity Level (SIL) Value on Three Phase Separator Application
Authors: Biyanto Totok R. , Natawiria Andika D. , Kusuma Franky , Musyafa Ali , Noriyati Ronny D. , Costa Sylvana D. , Irawan Sonny 
Published: October 2015

Abstract
Test interval is an action to verify Safety Integrity Function (SIF) availability. The detection of SIF availability is depends on appropriate test interval value. The test interval value could affect the value of Safety Integrity Level (SIL). This research proposed to demonstrate the effect of the test interval to the obtained value for the specified SIL on SIF. Therefore, SIL value will fit into the architecture of SIF. The case study that used in this paper is three phases separator. The save guards installed in this case are pressure SIF and the relief valve. The result of this research proved that the increasing value of test interval could increase the SIL value. The three phases separator case study with specific hazardous event frequency shown that 0.2 years or 2.4 months is the appropriate value for the test interval.
A Simulating Application of Well Production Allocation to Optimize Wax Formation and Pigging Frequency in Subsea Pipeline for a Gas-Condensate Field
Authors: Tran Nhat C. , Tran Nam H. , Ly Dao V. , Tran Nhut T. 
Published: October 2015

Abstract
Wax deposition is one of the most critical flow assurance issues for the pipeline and regular pigging is a popular method for dealing with them. Predicting and controlling the wax precipitation in the pipeline can help operators to optimize the pigging frequency, this in turn will create significant impact as subsea pigging can be very risky and costly. Yet wax deposition is also difficult to simulate as they are complex mixtures of heavy components from well fluid that freeze out when the temperature is low enough.
In this article, a methodology is developed to optimize pigging frequency. Simulation of wax deposition calculates the precipitation and dissolution due to the variation of fluid flow rate and inlet temperature into the pipeline. The simulation model takes into account all the heat transfer phenomena and hydrocarbon phase behavior along the pipeline. Due to the heat transfer along the production tubing from the reservoir to the well head, the tubing head temperature and respectively the pipeline inlet temperature increase with production flow rate from wells. In other words, the inlet temperature into the pipeline can be adjusted by the wells production allocation. This is one of the key factors that help to optimize the pigging frequency, as a proper wells allocation for a fixed production flow rate can give a high pipeline inlet temperature and flowing temperature, which can help not only to prevent wax formation but also to melt the wax that precipitated earlier.
The methodology is applied to a wax-riched gas condensate field in Vietnam. A proper well allocation plan has been developed, and as a result, the pigging frequency for the infield pipeline for this field can be optimized from conducting monthly to conducting yearly, significantly reducing risks and costs for the operator.
Automated Racking Board Pipe Handling System for Drilling Rigs Ensures Connection Integrity While Providing Safer Working Conditions and Consistent Tripping Speeds With Minimal Rig Modifications
Authors: Vogt Jim 
Published: October 2015

Abstract
Drilling operations, in general, are hazardous in nature and whatever can be done to alleviate this situation is important from a point of view of personnel safety and overall efficiency. Some of the most important drilling operations are pipe handling, tripping, and connection make up. These operations can be inconsistent, causing delays and potentially cause pipe or thread damage to the drill string. Further, these operations are some of the most hazardous on the drilling rig and can be exacerbated by personnel error, fatigue, environmental factors and inclement weather.
To address this, an automated racking board pipe handling system has been developed for land and bottom founded offshore rigs, which has the capability to address the following: Remove personnel from the mast/derrick and the "red zone" areas of the rig floorEliminate swinging pipe, accidental pin/stump contact, and misalignment (which can lead to drill string damage, instability, and added costs)Introduce efficiencies that potentially reduce overall drilling costs by extending pipe life and improving connection operationsControl from an HMI interface in the driller's cabin or via remote control on the rig floorMitigate inefficiencies due to inclement weather and/or environmental factorsEnhance safety in well control situations due to nobody working at elevationEnhance training & communication associated with the derrickman who is no longer working at heightInstallation with minimal modifications to the rig design (racking board modification only)
This paper will describe in detail the features of this automated system, which is compatible with land rigs (double and triple), jack-up, platform, and barge rigs. Additional case studies will show how this step change has been implemented on rigs to date.
Application of Pore Scale Network Modeling Technology for Waterflooding Oil Recovery Evaluation in Different Wettability Conditions
Authors: Zhenpeng Leng , Weifeng Lv , Qingjie Liu , Ninghong Jia , Jianhua Qin , Zhibin Jiang , Danyong Li 
Published: October 2015

Abstract
In oilfield development, waterflooding is normally characterized as an economical and efficient process, which leads to a considerable residual oil saturation. Wettability, being one of fundamental petrophysical properties which reflects interactions between reservoir rock surfaces and fluids during waterflooding, is an essential parameter in reservoir evaluation and simulation, and its effect on waterflooding oil recovery has often been a research hotspot. In this paper, the effect of wettability on waterflooding oil recovery is studied based on a pore scale network model which is a statistical structure of pores and throats extracted from porous media to conduct fluid flow simulation and characterize various physical and chemical effects. A new method combining micro-CT scanning and rate-controlled mercury injection experiment is applied to obtain pore structure data and to improve the representativeness of pore scale network. Multiphase fluid distribution and transportation in pores and throats are simulated by assuming quasi-static flow in pore scale network where both viscous force and capillary force are comparable. A special pore scale network simulation workflow is established, which is capable of simulating two intrusive simulation processes corresponding to oilsaturating with irreducible water and waterflooding, respectively. Wettability is applied in pore scale network model by randomly distributing contact angles onto pores and throats. Based on a series of numerical simulation experiments, it can be summarized that neutral wet condition always corresponds to higher oil recovery than water and oil wet conditions in the waterflooding process, which is consistent with adequate experimental results when preferential wet for one phase fluid is mild. However, simulation results from pore network show that the difference between oil recoveries of water and oil wet conditions doesn't remain constant, which indicates that effect of wettability should be linked with pore structure characteristic when assessing the oil recovery performance. On this basis, characterization of its effect on oil recovery through pore scale network modeling forms an important component of waterflooding development and research for new EOR methods.
Safety Climate Survey among Workers at Oil and Gas Company
Authors: Musa R. Abdullah , Fadli Achmad , Kusminanti Yuni , Erwandi Dadan , Lestari Fatma 
Published: October 2015

Abstract
BOB BSP Pertamina Hulu has been implemented Safety, Health & Enviromental Management System (SHEMS) since its establishment 12 years ago. The study is aimed to obtain the level of SHE perception and becoming values among workers. Survey was measured the safety values in the organization, working unit and individual level as the model of safety climate survey. Data collected through distribute the questionnaires among 436 workers from all levels, top management, middle managers and workers. The average of SHE perception in all workers is 2,28 (scale 1 to 4), as the organizational values is 2,23; as peer group values is 2,4; and as individual values is 2,24. It is indicate that the level of SHE awareness still in moderate level. Safety values that are higher than other safety values are personal appreciation of risk (score 2,57) and commitment management (score 2,53). The lowest safety values are communication (score 1,86) and personal priority and need for safety (score 1,90). Result show that HSE perceptions among employees are still need to be improved. It could be influenced by HSE communication and safety motivation was not effectively being implemented. Company may improve the SHE awareness through strengthening SHEMS implementation, improve the individual skill, safety competencies and two way communications regularly and more intensive.
Application of Thick Salt-Gypsum Formation Cementing Technology in KS Gas Field
Authors: Xueqing Teng , Zhongtao Yuan , Zhengqing Ai , Xiaochun Li , Feng Zhang , Jianguo Zeng , Aiping Liu 
Published: October 2015

Abstract
The most challenging cementing problems that been encountered in KS gas field of Tarim oilfield in China occurred in the salt-gypsum formation having the thickness of about 1000~3000m and the maximum depth of 7000m above. In most cases, there are high pressure saltwater layers among the salt-gypsum formation with the highest pressure gradient of 2.60g/cm3.
HPHT (130 MPa, 160 °C, BHST), ultra deep well and narrow safety density window with the density of about 0.07-0.12 g/cm3 brought huge problems which made the well cementing very hard to achieve good bonding quality, especially for production liner cementing. The qualification rate of cementing quality of the salt-gypsum formation section was only about 40% in 2013. The bad cement bonding quality was recognized as one of the main reasons for this issue, which was the one of the top headaches for the operator.
To answer these challenges, the ultra-high strength toughness casing, casing running downhole simulating technology, salt-tolerant spacer fluid and high density cement slurry, and step by step pressurized casing annular cement until cement set have been developed and applied successfully. The qualification rate of cementing quality of the salt-gypsum Layer section increased to 78% in 2014.
The successful application of these techniques improving cementing quality of the significant thick salt-gypsum formation under the extremely challenging downhole condition promoted the exploration and development of ultra-deep subsalt reservoirs in China.
An Attempt to Revitalize Watered-Out Gas Condensate Fractured Reservoir by Gas Injection
Authors: Adachi Y. , Hasegawa T. , Yamamoto H. , Hosokoshi K. , Anraku T. 
Published: October 2015

Abstract
This work challenges to the redevelopment of a mature gas condensate fractured reservoir with strong aquifer. Typically, fractured basement reservoirs have the inherent disadvantages; rapid decline rate, limited reserves, early water coning, and so on. Flow simulation model is built by an actual field data to evaluate lean gas injection even in watered-out gas condensate reservoirs. We verified the potentiality of gas injection method as EOR/EGR techniques in simulation case studies. The result of simulation study indicates that considerable amount of condensate can be recovered and the native gas can be recovered durng gas injection and reproduction.