bluuebunny/crossref_metadata_2025_split huggingface dataset:
Dealing with Complexity of Combination Traps in the North Malay Basin
Authors: Sriyarak Pakpoom , Anis Ahmad , Rungsai Khunamai , Bunpitaksakul Teerasak 
Published: May 2016

This reference is for an abstract only. A full paper was not submitted for this conference.

Abstract
The hydrocarbons production in the North Malay Basin, Gulf of Thailand, has been focused primarily on the post-rift reservoir formation, for example, Arthit and Bongkot Fields. The targets consist of mixed coarsening upward deltaic and crevasse splay deposits interbedded with fining upward channel deposits as well as organic-rich shales and coals. During the early phase of the development, wells were targeted and appraised mainly within the structural closure and/or the bright seismic amplitude anomalies. The well results show that the hydrocarbons were trapped even outside or beyond the structural closure as well as with or without seismic anomalies. Over the last few years, a number of wells including development, appraisal and exploration wells gave unexpected results either too good or too bad. The pre-drilled prediction and post-drilled results sometimes gave considerably difference both net pay thickness and hydrocarbon in-place. The seismic attributes are not always able to indicate the hydrocarbons accumulation.
While the nearby fields in the Pattani Basin, over thousand of development wells mainly targeted behind the faults where the structures up dip to the fault and found considerable amounts of pay along faults with no defined structural closures. The Probabilistic Method has been used to estimate the hydrocarbon in-place and the lognormal distribution has been applied for some volumetric parameters. The result has significantly improved both the drilling success and resources/reserves in the region.
This concept has been applied to the exploration and development in the North Malay Basin to cope with the geological complexity of the region. The large and beautiful structural traps were tested already. The rest would be stratigraphic and combination traps that always give unexpected results. Thus, the exploration and development strategy has been focused especially on the combination traps. This has been expected both to improve the drilling success and to increase the resources/reserves of the fields.
Benefits of PSTM and PSDM Reprocessing in the Exploration of the Deep Malay Basin
Authors: Charron Patrick , Ravaut Patrick , Riou Alain , Sirgue Jerome , Zuwaimi Mohd Noor 
Published: May 2016

Abstract
In May 2008 TOTAL E&P Malaysia (TEPMY) was awarded, together with his partner Petronas Carigali, two blocks with ultra HP/HT deep exploration targets. Work commitments on these blocks included seismic acquisition, reprocessing and drilling of two deep exploration wells below the conventional mature plays.
Imaging problems in the Malay basin are related to coal-bed multiples and absorption, pull-down effects and seismic resolution in a fluvio-deltaic to coastal plain depositional environments during Lower Miocene and lacustrine environment during the Oligocene.
To perform our "deep frontier exploration in a mature basin" TEPMY first analyzed available vintage dataset on the area. Most 3D seismic data have been acquired or processed in the last 10 years with long enough streamers (5 to 6 km) for our exploration targeting reservoirs from 2.5 to 5km deep. But vintage processing sequence was dedicated to conventional targets from 1 to 2 km deep, where imaging issues are limited.
TEPMY and his partner decided to reprocess all data covering identified prospects and leads on one block. New PSTM processing sequence was focused on multiple attenuation in target window with careful velocity picking and application of 3D-SRME despite shallow water depth. It results in a significant seismic improvement of lower Miocene sedimentary fairways imaging leading to exploration risk reduction. More reliable velocity analysis was also a key outcome in the evaluation of overpressure zone in the Malay Basin.
In parallel with time reprocessing, we have also launched depth reprocessing on the two main prospects of the southern block, prospect A and prospect B affected by strong structural uncertainties related to low velocity anomalies in several areas. Multi-approach accurate velocity model building strategy, including in-house Full-Waveform Inversion in shallower part, together with strong iterative interpretation input, leads to significantly improve structural image of the prospect B which now become a candidate for drilling.
We consider this time and depth reprocessing approach is a key parameter to properly evaluate deep exploration potential of Malay Basin as well as mature drillable prospects.
Investigations on Gas Trapping Phenomena for Different EOR-Water Alternate Gas Injection Methodologies
Authors: Bhatia Jigar Chandrakantbhai , Srivastava J.P. , Sangwai Jitendra Shital , Sharma Abhay 
Published: May 2016

This reference is for an abstract only. A full paper was not submitted for this conference.

Abstract
Water Alternate Gas (WAG) injection methods are the derivative of gas injection methods, wherein water and gas are injected intermittently. WAG injection can lead to improved oil recovery by combining better mobility control and contacting upswept zones and by leading to improved microscopic displacement.
Gas trapping in the reservoir after WAG process is an important parameter that affects the recovery of oil. Trapped gas refers to the immobile gas saturation remaining after the rock is flooded with oil or water. Trapped gas creates significant hysteresis effect (during drainage and imbibition) and reduces the relative permeability of water in the mixed wet or oil wet reservoirs.
In this work, gas trapping phenomena is presented for different WAG methods for a Indian Brownfield, namely, single, five cycle WAG, tapered WAG, five cycle WAG with Hydrocarbon gas (HC) and CO2 gas. Experiments are carried out on the recombined fluid in the core flooding apparatus at the reservoir conditions. The crude oil and gas is obtained from the separator at separator conditions and recombined at the reservoir conditions of 120 oC and 230 kg/cm2 at reservoir gas-oil ratio (GOR) to become representative of the reservoir fluid. The actual core sample is obtained from the field and is used for the study. The water and gas injection rate used for this study are 20 and 10 cc/hr, respectively, for all the experimental studies. Two types of gases are used for WAG method, namely, hydrocarbon gas (collected from the field and having about 90 % methane by composition in mole %) and CO2 gas. The results on the saturation of phases and Land's trapping constant have been calculated for several cases of production life cycle and for different WAG methods.
Making Wells Safer, Process Safety & Advanced Well Control Training
Authors: Van Den Brekel Bernd 
Published: May 2016

Abstract
Industry has to demonstrate to society that it can safely operate in challenging environments. This paper focuses on Wells and in particular well control, and discusses some process safety initiatives that will significantly contribute to keeping our license to operate. The first part will focus on some initiatives that Shell is currently implementing, whilst the second part will deal with advanced well control training.

Introduction
Process Safety means the management of hazards that can give rise to major accidents involving release of potentially hazardous materials, release of energy (such as fire or explosion) or both. Process Safety is distinct from Personal Safety in that Process Safety incidents may have catastrophic potential such as multiple injuries and fatalities, and massive economic, property and environmental impact. For well operations the recognised Process Safety hazards are related to well control and wellbore integrity (see figure 1).
Evolution of Well-testing Methods and Multi-phase Metering Techniques in Gas Condensate Fields in Central Oman
Authors: Al-Shukaily Alwaleed Rashid , Srinivas Mandalparthi Umamaheshwar 
Published: May 2016

Abstract
The gas development in Petroleum Development Oman (PDO) concessions commenced with the non-associated gas development from the Yibal field in the 1970s. The Yibal processing station incorporated permanent test separator facilities that allowed regular testing of the producer wells according to the field surveillance strategy. Yibal is a platform carbonate reservoir containing dry gas and was relatively straightforward for allocation using both wet gas meters at the well pad and test separator at the processing facility. Production from the gas condensate fields in Central Oman commenced with Saih Rawl and Barik fields in 1999 / 2000. The implemented metering methodology involved using conventional wet gas meters, venturi meters, installed at the well pad for single phase measurement. The wet gas measurement is then converted to dry gas and condensate phase measurements using a wet gas model (WGM).This model requires periodic update for giving the correct conversion to dry gas and condensate measurement. For the first few years, the mature gas fields relied on the tracer dilution techniques for measuring the produced fluid CGR and WGR. The multi-phase metering trials started in 2004 with the newly developed MFM provided by Schlumberger, VX phase tester. The post-trial assessment showed issues with the data repeatability with respect to CGR measurement and high dependency on the feed gas PVT which required frequent fluid sampling. The work in 2005 resulted in further maturation and refinement of the gas fraction technology and testing procedure using the VX and was followed by large scale implementation in the area. The ongoing study showed measurement uncertainty of condensate measurement reaching 20% and higher which instigated further research into alternative metering solutions.
An extensive well-testing study was initiated in 2009 and completed in 2011. It was focused on meeting the key reservoir surveillance targets such as wellhead allocation of gas and condensate, fluid characterization among other well and reservoir management objectives.
The evaluation process adopted by the government gas directorate team involved examining the leading multi-phase metering technologies and their field applications through vendor and operator discussions in addition to field qualification trials. The results of the study were benchmarked against the functional standards set by the company.
This paper will describe the journey of wet gas metering application in Central Oman gas condensate fields, challenges that were experienced, the screening process for the multi-phase metering technologies leading to the adopted solution by the gas group in PDO.
Prediction of Solid-Vapor-Liquid Equilibrium in Natural Gas Using ANNs
Authors: Shuker Muhannad T. , Ismail Firas 
Published: May 2016

Abstract
In the last five decades, several studies have been performed on the measurement and predication of hydrate forming conditions.
Many correlations were presented in the literature, but most of these correlations considered pure gases and their mixtures which leads to low accuracy.
In addition, some of these correlations are presented mainly in graphical form, thus making it difficult to use them within general computer packages for simulation and design.
The purpose of this work is to present a comprehensive neural network model for predicting hydrate formation conditions for pure gases and gas mixtures. The neural network model enables the user to accurately predict hydrate formation conditions for a given gas mixture, without having to do costly experimental measurements.

Introduction
Gas hydrates are ice-like crystalline compounds, inclusions. Their stability occur through occupation of suitable size gas components (guest molecules) into cavities formed by water molecules (host molecules)[1]. In 1810 hydrate was firstly discovered by Sir Humphrey Davy. During the first 100 years after the gas hydrates discovery, the interest in these compounds was highly concerned with the identification of (a) the species that can form hydrate and (b) the pressure and temperature conditions at which the formation occurs. Recently, naturally occurring clathrates hydrate in the earth which contain mostly methane are regarded as a future energy resource [2]. Clathrate components are mainly two structures structure I and structure III, although structure II has also been known. Most studies of gas hydrates have concentrated upon measuring the three-phase dissociation pressure however; few data are available for (H-Lw) phase equilibria [3]. In 1934, it was recognized that the plugging of natural gas pipelines was due to formation of hydrate of natural gas.
Typical operating problems include the fouling of heat exchangers and other vessels, erosion of expanders, in addition to plug gage of transmission lines with the solid hydrate [4]. The best method for determining conditions of hydrate formation is to measure the formation experimentally at the temperature, pressure and composition of interest. It is impossible to satisfy the infinite numbers of conditions for which measurement are needed. Hydrate formation prediction methods are needed to interpolate between measurements. However, such experimental endeavors are both time consuming and expensive relative to industrial needs for a number of hydrate formation conditions. Therefore some means of interpolation between the experimental results are needed, and ideally the interpolation could be extrapolated beyond the condition of the data. The petroleum industry spends millions of dollars to combat the formation of hydrate. So, the accuracy of estimating the natural gas hydrate is extremely important for optimizing the cost of piping systems and processing units.
Improved Performance with New Casing while Drilling Bit Design Elements - Development and Case Studies
Authors: Chung Chay Yoeng , Abdul Razak Ahmad Hakam , Tan Ming Zo , Ugwuocha Sharp , Twardowski Eric , Won Shao Wang Keith , Beattie Scott 
Published: May 2016

Abstract
Casing while Drilling (CwD) is an effective means of mitigating hole stability and lost circulation problems in many parts of the world. In recent years this technology has become a standard part of a drilling engineer's toolkit resulting in a reduction of flat time and more cost effective means of drilling surface and intermediate hole sections. The popularity of Casing while Drilling stems from the ongoing success in the Asia Pacific region, where softer rock strength and high rig rates make it a cost effective technology.
In many parts of the world, operators are faced with significant drilling hazards in areas with harder or more abrasive formations. However, unlike conventional drilling, the current selection of CwD bits has been limited for these types of applications.
The design of the casing bit must improve drilling performance and effectively enhance the economics, while still retaining the ability to be drilled out without damaging the polycrystalline diamond compact (PDC) cutting structure of the drill-out bit. There are a number of Casing while Drilling bits on the market with various types of cutting structures. Some are readily drillable, utilizing soft materials but with limited longevity. Others are designed with robust cutting structures, delivering enhanced performance in hard formations, but may require additional drill-out, milling, and clean-out trips. Finding a balance between durability and ease of drill-out is an ongoing challenge.
This paper will introduce new CwD bit design elements, development testing, operational efficiencies, and several case histories, and will also highlight a number of key successes - particularly the optimized drilling performance and ease of drill-out without the need for a specialized drill-out bit.

Introduction
Well construction costs have been escalating significantly over the past decade especially in the offshore segment where rig costs have more than tripled (Figure 1), spurring both operators and drilling contractors to search for methods of reducing drilling flat time. The century old Casing while Drilling (CwD) technology hence received renewed interest and has been further improved and deployed in many geological areas since the late 1990s.
There are two mainstream CwD technologies, namely the retrievable and non-retrievable systems, sometimes referred to as the latch system and cement-in-place system, respectively (Fisher et al, 2004). As the name implies the latch system involves latching the bottom-hole assembly (BHA) into the first joint of casing. Drilling torque is transmitted to the bit either from surface via the casing string, or generated by a downhole motor as a component of the BHA, enabling the bit to turn independently of the casing. Upon reaching total depth (TD), the latched BHA (including the bit) is pulled out of the hole prior to cementing.
Accelerating Time-to-Autonomy for Technical Staff - Developing the Industry's Best Performers
Authors: Schaaf Michael , Garg-Buck Anu 
Published: May 2016

Abstract
Shell has publicly stated a production target of 4 mboe/day by 2018. This will require the recruitment and development of a large number of technical staff both recent graduates as well as experienced professionals. Shortening time to autonomy and time to integration respectively is critical to success. Structured programs are industry proven vehicles to achieve this and to provide the assurance that staff are truly competent to do what they are required to do. In addition, competence driven development programs offer a clear performance and competence bar.
This paper describes Royal Dutch Shell's approach to developing this critical pipeline of technical professionals by outlining the necessary and sufficient conditions for success of the Shell Graduate Programme, the Advanced Technical Programme and our approach to integrating Experienced Hires.
The Shell Graduate Programme is an integrated approach that combines formal learning, with on the job tasks, active involvement of technical coaches and line managers and standardized methods of competence assurance. Not only does this follow the 70/20/10 methodology of learning but also results in the expected "time to autonomy" for graduate joiners being reduced by 1 to 2 yrs as compared to other less comprehensive approaches. In addition to closing critical capability gaps in the business, this is also a clear component of the Employee Value Proposition as Generation Y graduates today look for faster and more structured progression when selecting their employer of choice.
The Advanced Technical Programme which is aimed at staff exiting the Shell Graduate Programme as well as experienced hires with only a few years relevant business experience, builds on the Graduate Programme and uses the same structures and principles. It focuses on developing technical professionals to make nonstandard, original technical decisions autonomously (and similarly follows the principles of blended learning combined with active involvement of Leaders.
Finally shortening time to integration for Experienced Hires is critical to enable them to deliver for the business and a clear retention lever. The development of a single, comprehensive onboarding programme maximizes the impact experienced professionals have by accelerating the time to integration into Shell and enabling experienced hires to blend their past experience with the 'Shell Way'.
Application of a New Method to Estimate Free Fluid Level and Recognition of Compositional Grading Using Wireline Formation Testing Data
Authors: Khajooie S. , Qassamipour M. , Farhani M. 
Published: May 2016

Abstract
Determination of fluid contacts in a hydrocarbon reservoir is extremely important in calculation of initial hydrocarbon in place and field development planning. The uncertainty in the present fluid type and fluid levels may have a significant impact on the reserves estimation and well completion strategies. Wireline Formation Testing is widely used to discover fluid contacts (or its generic term, Free Fluid Levels). Precise analysis of pressure data obtained from these tests is crucial in defining the type of fluid and fluid contacts.
Although the traditional method of P-D Plot to determine a Free Fluid Level(FFL) is easy to implement, however it has the disadvantage of lack of information on uncertainty of the analysis. It is often difficult to identify and remove noisy data which may result in inaccurate estimation of contacts.
A method has been mentioned in the literature by which Fluid Level is discovered using formation pressure data that are projected to a datum depth. With this method, it is very simple to find noisy data points which contribute to uncertainty in the FFL estimates. Another benefit of applying such method is to authenticate compositional grading presence in the reservoir. Also it can discriminate layers with different pressure behaviors in a multilayered reservoir.
In this paper, several wireline formation testing data such as data from MDT and RFT tools -in different fields in Middle East- have been analyzed by previously mentioned method. A good agreement was observed between the results of this method and other data like petrophysical interpretation, geological evidences, DST results and finally PVT analysis. Also a correlation has been developed to confirm existence of compositional grading and a strategy has been proposed to calculate the rate of density change with depth in those reservoirs where variation of density is not extremely nonlinear.
Well Failure Detection for Rod Pump Artificial Lift System Through Pattern Recognition
Authors: Liu Feilong , Patel Anilkumar 
Published: May 2016

Abstract
Rod pump is by far the most widely used artificial lift method within the oil industry to improve the oil production for reservoirs with energy levels too low to lift fluids to the surface. It is roughly responsible for about two-thirds of the artificial lift producing oil wells. Well failures, including surface, reservoir and down-hole failures, in rod pump artificial lift systems commonly occur, leading to substantial downtime, production loss and operation expense. Correct identification of well failures and scheduling appropriate maintenance will reduce inappropriate repairs, minimize downtime and subsequently improve operation efficiency.
This paper presents a systematic Pattern Recognition approach to detect the well failures. In this method, we start with the pattern recognition workflow, explain how we choose the right data and define good features based on the domain knowledge and how we extract features utilizing signal processing techniques. Finally, we will describe how we establish the classifiers via heuristics instead of training. Through this practical application of pattern recognition, we describe some fundamental concepts and steps to build a successful application using pattern recognition technologies.
This method was firstly tested on one year history data of 100 rod pump production wells from an active oilfield and the results were compared with the state-of-the-art method from Liu et al (2010); and then on six months of history data of 100 rod pump production wells. The pilot test results showed that our method could correctly identify the well failure with success rate of 82–86% and only 11–15% of false alarm. Comparing to Liu's the state-of-the-art method (2010), our method has much lower false alarm rate while with similar success rate of detecting failure, thus confirming that our systematic method is more capable of detecting well failures successfully.