bluuebunny/crossref_metadata_2025_split huggingface dataset:
New Phase of Formation Evaluation in the Gulf of Thailand
Authors: Duangprasert Tanabordee , Daungkaew Saifon , Paramatikul Ronarong , Vincent Regis 
Published: May 2016

Abstract
The Songkhla field in the southern Gulf of Thailand was put on production by CEC International (Thailand) in early 2009. As with any relatively small field development, it was important to optimize capital investment and formation evaluation technologies selected in order to minimize risk and total cost by making the proper field development decisions.
Formation evaluation is challenging in this field where fresh formation water, laminated shaly sands, low gas-oil-ratio (GOR), waxy oil, and low permeability are all present. This environment causes low contrast in formation resistivity between oil and water, making log analysis difficult. Small errors in clay volume and porosity have such a large impact on the resulting saturation computation that it is sometimes difficult to compute an accurate saturation or even determine if the zone is hydrocarbon bearing. Variable oil viscosity and permeability also make development planning especially difficult.
This paper aims to demonstrate the challenges of formation evaluation in such reservoirs and the uses of new formation evaluation technologies to help overcome these issues from number of wells in Songkhla basin. Several acquisition technologies have been introduced to improve the formation evaluation:(1) A new Downhole Fluid Analyzer (DFA) tool has been developed to enable evaluation of low GOR oils, and to conclusively identify the formation fluid, zone by zone, and to optimize completion selections.(2) A high performance dual packer module was combined with the new DFA technology to evaluate the feasibility of developing lower quality parts of the reservoirs.(3) A cased hole formation tester was deployed to identify reservoir fluid identification in one particular zone where the reservoir fluid was not conclusively determined when the well was first evaluated.

Songkhla Field background
Since late 2008 CEC International (Thailand) Ltd (formerly NuCoastal Thailand Ltd) has drilled more than 30 wells in the Songkhla Basin. To date approximately 4mm bbl crude have been produced from reservoirs of lower Oligocene, Miocene and Eocene age using using electric submersible pumps (ESPs) and a mobile offshore production unit (MOPU) with crude piped to a tanker. The Lower Oligocene reservoir is typically at around 8000ft TVDSS and has porosities in the range 18- 20%. The produced oil is a medium sweet grade with an API gravity of 29° and a low GOR of around 100 scf/bbl.
Formation evaluation is challenging in this field due to the presence of fresh formation water, laminated shaly sands with low permeabilities. The resulting low contrast in formation resistivity between oil and water makes the identification of water saturations and oil pay difficult. In this context a number of formation evaluation tools were used to better understand the nature of the fluids.
3D-VSP and Surface Full-azimuth Seismic Integrated Study in Daqing Oil Field
Authors: Li Yanpeng , Ling Yun , Chen Yuanzhong , Gao Jun , Xu Gang , Chu Fangdong 
Published: May 2016

Abstract
Along with the progress of VSP techniques, especially the improvement of downhole geophone manufacture and VSP data processing methods, now the survey mode has developed from zero offset VSP, offset VSP to Walkaway-VSP, Walkaround-VSP and 3D-VSP corresponding to different geological objectives. VSP techniques have obtained partial success in parameter estimation, high precision imaging and reservoir characterization, but obtained dataset is range limited and imaging still need to be improved. In order to broaden the range of survey and expand the advantages of VSP to surface seismic, large array 3D-VSP and full-azimuth surface seismic survey were carry out in XJWZ area of Daqing oil field. The reservoir of this area is mainly formed by volcanic and its distribution is very complex due to many periods of volcanic overlap in this area. Previous seismic surveys are mainly 2D and narrow azimuth 3D, the results still cannot be used for anisotropy analysis and fracture discrimination effectively, say nothing of satisfying the requirements of developing plan establishing. So a joint survey of 3D-VSP and full-azimuth surface seismic was implemented. This project tries to combine the advantages of VSP and surface seismic, measuring in borehole and surface simultaneously. Thus, real three-dimensional survey was achieved. Some comprehensive studies are presented in this paper, these research work include: 3D-VSP and full-azimuth surface seismic simultaneous survey design; Q factor and anisotropy parameter estimated from VSP and applied to 3D seismic processing; characterize reservoir and predict gas saturation with final images. The interpreted results have been used for well drilling and wet gas has been founded, so the validity of this method has been proved.

Introduction
The work area studied here is located in northeast part of China. Objective is a gas-bearing volcanic reservoir. The formation and distribution of volcanic reservoir in this area is extremely complicated (Figure 1). It is shown in early-stage study that the YC Formation in this area is characterized as a very complicated vertically superimposed structure due to numerous volcanic eruptions (Figure 2). Volcanic rock holds a sensitive spatial variation in its lithofacies. In the past, only the 2D and the narrow-azimuth 3D surface seismic surveys were carried out in this area, which have a certain limitation in identifying the anisotropy of volcanic rocks and the fracture zones, and therefore can not meet the requirements on working out the development program for the oil field at latter stage.
Predicting Marginal Marine Reservoir Architecture: Examples from Asian Shoreline Systems
Authors: Ainsworth Bruce , Vakarelov Boyan 
Published: May 2016

Abstract
Sequence stratigraphy is often used to link coastal depositional style to specific systems tracts. Even though such an approach has merit, it is argued that other variables, such as basin setting, distance from a shelf edge, local physiography and shoreline shape are more useful for predicting shoreline architecture, especially when it comes to the effects of waves and tides. This is because shorelines in different systems tracts can be exposed to similar combinations of processes, which have a first order dependence on the shape of the marine basin fronting them.
To test the above hypotheses, we performed process-based analysis of 416 modern marginal marine systems from Asian coastlines, which show large variability of basinal, shelfal and local coastal physiographic conditions. Each system has been characterized in terms of architecture and basin setting, which can then be compared.
Architecture is defined using a check-list of geomorphologic criteria such as presence of beach ridges and beach ridge sets, presence of tidal channels, degree of tidal funneling visible at the mouths of fluvial channels, presence of tidal flats, measure of lobateness of the shoreline, among others. Using such criteria, the systems have been placed into one of fifteen process classification categories from defined by Ainsworth et al., (2011) (W; Wt, Wf; Wtf; Wft; T; Tw; Tf; Twf; Tfw; F; Fw; Ft; Fwt; Ftw) that reflect the relative impact of wave (w), tide (t), and fluvial (f) influence at a shoreline.
Basin setting parameters describe whether a system occurs on a narrow shelf (&lt;75km), wide shelf (&gt;75km), small embayment (&lt;50km), large embayment (50–500km), a seaway (&gt;500km), a combination of these, as well as additional parameters describing levels of shoreline protection (partially protected; protected; enclosed).
The results of the study show statistically significant, probabilistic relationships between basin setting and process classification which can potentially be used in a predictive manner in the subsurface. It is shown that over 90% of systems on narrow shelves belong to one of the wave-dominated categories (W, Wf, Wt, Wft, Wtf), with the vast majority of these belonging to the W and Wf category. It is also shown that the wave-dominated proportion significantly decreases on wide shelves, large embayments and continental seaways, where wave-dominated systems occur only 55–65% of the time, with tide-dominated and fluvial dominated systems becoming proportionally more important. Such systems also show overwhelming dominance of mixed influence categories. This is important since the mix of process influences results in increased heterogeneity in the systems. This then escalates the risk of stratigraphic reservoir compartmentalization in the subsurface.
Karst Modeling of a Miocene Carbonate Build-up in Central Luconia, SE Asia: Challenges in Seismic Characterization and Geological Model Building
Authors: Chung Elvis Kang Yeu , Ting King King , AlJaaidi Omar 
Published: May 2016

Abstract
The development of the Central Luconia carbonate build-ups were strongly influenced by the interplay between eustatic sea-level and basinal tectonics. The Alpha field addressed here is one of the seismically best imaged isolated carbonate platforms in Central Luconia and dendritic features, interpreted as karst, were found to be very prominent throughout the field. Karst is a diagenetic facies, an overprint in sub-aerially exposed carbonate bodies produced and controlled by dissolution and migration of calcium carbonate in meteoric waters. The exploration well in the Alpha field encountered total losses while drilling which was believed to be as a result of drilling in to karst (common in Central Luconia carbonates). Some of the best features from Petrel, Landmark and Shell software packages have been integrated to generate an attribute volume for karst interpretation. Using Petrel Geobody, multiple 3D box probes with short time gate and optimum clipping value were used to extract the karst Geobodies. Using a short time gate box probe is crucial for CPU/memory performance and most importantly, to have better control on editing noise and non-karst signal later.
Karst has a big impact on well planning (problem with losses and completion length), the hydrocarbon volume in-place as karst provide substantial secondary porosity; and well management and development strategy (wells nearer to karst are more likely to water-out quicker). This study incorporated an integration of well data, seismic characterization and geological understanding of the field and near-by analogues in building a subsurface model for field development.

Geology
The Central Luconia Province is located in offshore NW Borneo. The province is delineated by two major strike-slip faults, the West Baram in the northeast and the Rajang line in the southwest (Figure 1). Seafloor spreading in the South China Basin during the Oligocene to middle Miocene resulted in formation of a horst graben system that which controlled distribution of subsequent reefal carbonate growth. At mid-late Miocene reefs developed preferably on horst blocks (Mohammad Yamin Ali & Abolins[1]). Two major factors controlling carbonate sedimentation in the Central Luconia province are the regional tectonics and eustatic sea level changes. Tectonics played a role in creating horst and graben structures which served as basement for the onset of carbonate deposition and exerted an influence on the size and shape of the build-ups (Ting et al[2]). The latter also dictated the type of the depositional facies and their distribution which governed the reservoir properties of the carbonate platform.
Study and Application of Carbonate Reservoir Characterization in Block-B on Eastern Margin of Pre-Caspian Basin
Authors: Chen Hongtao , Li Jianying , Yang Feng , Li Yibao 
Published: May 2016

Summary
Carbonate sedimentary facies division and reservoir prediction are the problems that have obsessed the petroleum industry for many years. Combined with the regional sedimentation evolution background of Block-B on the eastern margin of the Pre-Caspian Basin and reservoir features dominated by primary porosity indicated by drilled well, this paper performs the stratigraphic sequence division under the carbonate platform sedimentation background firstly, and secondly, performs division and optimization of seismic facies and sedimentary microfacies within different system tracts, and indicates that tidal flat and dolomite flat microfacies of restricted platform subfacies within the high system tract of sequence KT-I are the most favorable reservoir development facies in Block-B. Based on fine correlation and calibration of system tract, qualitative and semi-quantitative prediction are performed for reservoir planar distribution within the favorable reservoir facies with adoption of multiple geophysical methods such as seismic attribute analysis and well logging constrained inversion. Drilling exploration is implemented for TLW structure by overlapping structural mapping result, high yield hydrocarbon flow is acquired and TLW large-scale oil and gas bearing structure is observed, which is the largest discovery of Kazakhstan land exploration in the past decade. Drilling result has verified the reliability of the study.

Introduction
Block-B is located to the southeast of Zhanazhol Oilfield, Aktoube State, the Republic of Kazakhstan, and structurally is located at the slope of transitional zone from the Astrakhan-Aktubinsk uplift to the southeast depression zone (Figure 1). During the Hercynian orogeny, the block uplifts integrally at later stage, which is the final directing zone of oil and gas migration with quite favorable regional structural position.
At present, the drilled results in the study area confirms that carbonate rock of Carboniferous system are the main target layers of the working area, and have obvious anisotropism. Due to the quick lateral variation of the reservoirs, it is very difficult to predict. Therefore, the improvement of reservoir prediction accuracy is one of the key factors for acquiring successful drilling.
Seismic-While-Drilling Checkshot Survey on High-Inclination Well-Beyond the Time and Depth
Authors: Ahmed Aqil , Lim Teck Kean , Wuertz Walter , Kanaree Maneerat , Pirie Wayne Scott , Rebel Pieter 
Published: May 2016

Abstract
In many drilling environments, recording checkshots using logging-while-drilling (LWD) services mitigates drilling risk by obtaining time-depth information to position the drillbit on the seismic map. In high-inclination wells, acquiring these data can be both time-consuming and problematic. Seismic while drilling, however, faces the high-deviation challenge without additional rig time. It can be used beyond the time-depth application by using recorded waveforms as vertical seismic profiling (VSP).
A drilling campaign offshore West Malaysia included several development wells (J and S types). As these wells were on the edge of the field, checks hot information was required to confirm the existing velocity model for the area. Uncertainty in the velocity model was caused by the presence of shallow gas clouds. By applying seismic-while-drilling technology and running it in the LWD bottomhole assembly (BHA), seismic checkshots were acquired while tripping out of the hole. This procedure was completely transparent to drilling operations, as shots were acquired only during pipe connections.
The seismic source wavelet was produced by a 3×150??in.3 sleeve air gun array deployed from the survey vessel. Although the tool has no active coupling, the high wellbore deviation ensures adequate coupling between the sensors in the BHA and the formation. Survey and connection information was transmitted sing ultrahigh-frequency (UHF) radios, and dedicated navigation ensured the vessel was on station ahead of time. The checkshot data agreed well with the predicted model and provided a useful verification of its validity. The recorded waveforms produced an image with higher resolution than the surface seismic below the well path for reservoir delineation. Also, seismic phase and time matching between the corridor stack and the surface seismic were conducted to characterize the embedded seismic wavelet and assist with reservoir interpretation.

Overview
Acquiring checkshot data can be both time consuming and problematic in high-inclination wells using conventional wireline methods. With the advent of seismic while drilling, we can now eliminate these problems and efficiently acquire checkshot data in highly deviated wells.
This case study demonstrates the practical application of existing seismic while drilling technology to reduce both time and cost to the client in acquiring a vertical incident VSP (VIVSP) survey offshore Malaysia.
Hybrid Power Generation for Offshore Wellhead Platform: A Starting Point for Offshore Green Energy
Authors: Rongsopa Roongwit 
Published: May 2016

Abstract
The purpose of this paper is to present the DC power supply for unmanned remote wellhead platforms (WHP). In several recent WHP projects, there are a number of difference aspects in Bongkot and Arthit Fields in the PTTEP's Gulf of Thailand and one of them is the DC power supply. PTTEP by Wellhead platform department intends to standardize the design of DC power generation for Generic Wellhead Platforms (Generic WHP) for either Bongkot or Arthit fields.
Offshore wellhead platforms have been powered by various power generation technologies such as Gas engine generator, Diesel engine generator, Closed cycle vapor turbogenerator (CCVT), Thermoelectric generator (TEG) including renewable energy technologies such as Solar power system and Wind turbine generator. Both Solar power system and TEG are widely used as DC power generation for offshore remote wellhead platforms to power platform DC loads such as PLC, SCADA, and Radio system.
Technical evaluation for various DC power supply will be presented. The scope of this paper is to discuss and recommend the most suitable DC power generation configuration for the Generic Wellhead Platforms focus on techno-economic with consideration of optimum point of reliability, economy, and environment.
In addition, all calculations of system equipment sizing for the selected DC power generation configuration for generic WHP will be detailed in this paper.

1. Introduction
The existing wellhead platforms (WHPs) of PTTEP in Bongkot and Arthit field are equipped with various types and configurations of DC power generation system. The Bongkot WHPs in old phase (e.g. phase 3E, 3F and 3G) are equipped with Closed Cycle Vapour Turbogenerator (CCVT) as main DC power generation, while the recent development Bongkot WHPs phase 4A are equipped with Thermoelectric Generator (TEG). The TEG system has been also installed in Arthit WHPs phase 1A (i.e. AWP 2–6). During design development for Arthit WHPs phase 1B (i.e. AWP 7–10), the Solar & TEG hybrid DC power system was first introduced and implemented as main DC power generation system for PTTEP WHPs in order to improve platform power availability and reliability. The Solar & TEG hybrid DC power system has been continuously used for recent Arthit WHP development project such as Arthit North project.
Gas Flare Reduction Through Operational Enhancement and Innovative Modification & Projects
Authors: Al-kandari Ali Hussain , Veeraraghavan Ashok Kumar , Saqeq Omar Ali 
Published: May 2016

Abstract
Description:Kuwait Oil Company (KOC), over the past few decades has significantly increased the Oil production to meet the ever increasing global energy demand. In this process, the production of associated gas has also gone up many folds, surpassing the Gas handling & exporting capabilities. KOC-West Kuwait(KOC-WK), surface handling capacity expanded by three folds in 2001 while the associated gas handling facilities was short of requirements due to improper gas production estimates. This resulted in significant gas flaring, more than 70%, leading to substantial revenue loss and environmental impact.
Application:KOC with its commitment to corporate & social HSE performance has demanded KOC-WK to bring down the annual flaring targets to 1%. Accordingly, Flare reduction road map was drawn with short term and long term plans to meet the company flaring targets. Some of the quick wins were a) Improving operational efficiency of equipments & operating crew, b) Identifying imbalance in gas handling capacities and redistribution among facilities. c) Improving Gas export quality through continuous operation of dehydration & refrigeration system. Some of new projects planned and being executed are a) Centralized Gas Booster station b) Additional transit lines, slug catchers c) Gas sweetening & Gas re-injection facilities at KOC, d) Capacity redundancy of AGRP plants.
Results:The short terms measures were completed by 2009 resulting in flare reduction from 70% to 12.5%, while the long term initiatives will ensure the flare reduction to 1% by 2013–14 and meet the company targets.
Significance of Subject Matter: The Key initiatives which brought about the flare reduction were internal modifications, incorporation of latest technology in new projects, increased awareness among operating crew and establishment of effective coordination and monitoring systems.