bluuebunny/crossref_metadata_2025_split huggingface dataset:
Aligning Shutdown Plans of Multiple Projects to Minimise Production Loss - 3 Years Look Ahead Model
Authors: Al-Jabri Saleh Mohammed , Kumar Kenneth Prem , Al-Qazweeni Mahdi Mohammad 
Published: March 2015

Abstract
Description: Marked by rapid expansion and revamp, year 2012–13 for KOC's NK directorate experienced situation wherein each of the operating facility (3 Gathering Centers- 450MBOPD, 1 Water Injection plant-300 MBWPD; 1 Sea Water Treatment Plant-300 MBWPD) required multiple Shutdowns to cater for Tie In requirements of 5 different projects (different time lines) & Preventive Maintenance.
Catering to individual project shutdown requirements meant huge production loss and the only way feasible to minimize the same was to accommodate Tie In requirements of all projects, in parallel within a single or maximum two shutdowns per facility. To minimize these losses, KOC concentrated on program management focusing on interfaces between projects to develop a feasible aligned shutdown plan and to accomplish it successfully across all facilities.
The paper intends to highlight critical elements of the planning & implementation phases of the aligned shutdown plan like; Tie In scopes (all disciplines) & schedules specific to each project, tools used for decision making, Identification & management of risks and project interfaces, communication management, resource management, monitoring progress and coordination (12 KOC Teams & 5 Contractors).
APPLICATIONS: All Brownfield projects
RESULTS & CONCLUSIONS:Savings of more than 1000 million USDSafety Enhancement by avoiding repletion of hot works on critical Hydrocarbon lines (Tank Vapor header, Flare header etc.)Reduction in Flaring.Reducing the number of shutdowns helped minimizing numerous startup & shutdown problems associated with ageing facilities.
With the availability of PM shutdown every year, aligning project Tie had been relatively easier; however with the concept of partial shutdown for Preventive Maintenance, shutdowns of long durations won't be available. Thus, in future Facility Shutdowns of long durations will have to consider addressing Tie In requirements of all projects (3 years look ahead) irrespective of project stage.
Sedimentology and Diagenesis of Deeper Clastic Reservoirs: Some Insights from Recent Exploration Wells in Offshore Sarawak, Malaysia
Authors: Pendkar Narender , Bt. Zainun Fakhitah , Parsuram Satyabrata Nayak , Bin A. Aziz Anuar , Bin Ali Mohd Firdaus , Bt. Embi Rahida 
Published: March 2015

Abstract
The present study integrates the laboratory data from sidewall cores (RCA, petrography, XRD and SEM) with sedimentological observations (cores, wireline and image logs). Compositionally the sandstones are fine to medium grained sublitharenites to litharenites, with lithic fragments of metamorphic, reworked sedimentary and volcanic rock types. The diagenetic events observed in the sandstones are compaction, dissolution of feldspar and lithics, cementation (pyrite, silica, calcite, siderite dolomite and ferroan carbonate), and clay formation (kaolinite and illite). The porosity type comprises of primary intergranular, secondary and microporosity. The environment show a gradual change from upper reaches of the lower coastal plain with fluvial dominant regime for Cycle I to lower reaches of the lower coastal plain with increasing marine influence in Cycle II. The reservoir quality is controlled by both petrofacies and grain size variations.

Introduction
The ongoing drilling campaign in offshore Sarawak has resulted in the discovery of potential reservoirs from deeper Cycle I and II, previously considered tight and thus opening new frontiers for exploration. The study area lies within several geological provinces of Central Luconia, SW Luconia and West Balingian (Figure 1 and 2). The generalized stratigraphy, tectonics and paleogeographic evolution for the Cycle I and II are depicted in Figure 1 (Madon, 1999). In the subsurface the Cycle I and II sediments can be recognized using biostratigraphy, well logs and to a limited extent on seismic datasets; the concept of Cycle as originally defined by Ho Kiam Fui (1978) has been used for defining the cycle boundaries. Accordingly, the base of a cycle is taken for practical reasons at the base of the most transgressive interval. The electrolog signatures across the block show good lateral correlations and can be used with reasonable confidence (Figure 2).

Methodology
The present study was undertaken to comprehensively evaluate the sedimentological controls for understanding the reservoir quality from eight exploratory wells obtained during the last few decades. The observations and datasets from limited conventional and sidewall cores form the basis of this study. Laboratory data (RCA, petrography, XRD and SEM), wireline and image logs were integrated to understand the petrofacies, diagenesis and depositional trends. The petrographic, mineralogical and textural data is limited especially for the deeper Cycle I sandstones. The analytical datasets have been standardized and plotted to make meaningful interpretations and comparisons. For understanding the sandstone compositions, the modal data obtained from petrographic examination was plotted using Folk (1980) techniques for classification of sandstones and lithic grains.
Integration of Rock Physics Model in Reservoir Characterization - a Case Study from Malay Basin Malaysia
Authors: Pathak Ravi Kant , Ali Zulfiqar , Bakar Rizal 
Published: March 2015

Introduction
Rock physics is considered as essential link between reservoir & seismic properties that allows improved reservoir characterization. While petro-physical evaluation provides information about 1D lithology, porosity and saturation information, rock physics add value in their interpretation in terms of geological control over reservoir development and fluid mixing model such as uniform or patchy saturation. Rock physics models developed based on integration of well and core data facilitates reliable prediction of reservoir properties beyond the well control from elastic properties estimated from seismic data. In the paper, authors demonstrate the value gained through establishment of rock physics model from well and core data and its potential application for improved prediction of reservoir properties in Malay basin.
The study area is a part of Malay basin located 170 Km offshore Terengganu at about 76 M water depths. The field is an E-W elongated four way structural closure. The reservoirs are 3–10 M average net thickness comprised of middle to upper Miocene fine-grained sand and silts inter-bedded with clay & coals deposited in a coastal plain setting.

Rock Physics Diagnostics
Rock Physics diagnostics (RPD) has emerged as a tool to establish the relationship between seismic velocity and porosity consistent with geological control over reservoir development to support the development of Rock Physics Model. In the study, the solid phase components and their proportions have been established from Sand-Slilt-Clay (SSC) model. Figure 1 shows the reservoir lithology and fluid characteristics as established from Petro-physical evaluation of a representative well within the study area.
Imaging on the Edge - Processing Challenges of a Sparsely Acquired 3D-2C OBC Survey, Offshore Malaysia
Authors: El Kady Nabil , Ghazali Ahmad Riza , Hoong Tang , Widjianto Yeni P. , Chandola Sandeep Kumar , Sharma Sachin Kumar , Abdul Rahman Mohd Ramzi , Nyein Glenn , Sazykin Artem , Goswami Saumya Kanti , Hamdani Ahmed 
Published: March 2015

Introduction
Seismic data acquisition using ocean-bottom cable (OBC) methods, whilst capturing valuable azimuthal information, often presents challenges in the signal processing sequence for successful removal of unwanted noise and multiples-related energy. Herein, we present the results of methods that have enhanced the standard noise and multiple attenuation workflows. We present results on linear noise and shear-wave removal utilizing wavelet scale decompositions to complement tau-p transforms, receiver and source line interpolations using a "beyond-aliasing" approach for improved multiple model prediction and also subsequent imaging, and wavefield extrapolation to sea level plus adaptive subtraction for long-period multiples removal.
Whilst it is always desirable to acquire data with uniform and dense coverage, acquiring 3D OBC wide-azimuth surveys can be challenging and expensive due to limits imposed by operational complexity and safety, time scheduling due to weather windows and environmental considerations, in-situ infrastructure and obstructions, and others. This typically results in compromises to surface acquisition grid sampling, i.e., large source and/or receiver line spacing. To mitigate the sparseness of OBC acquisition, an innovative and cost-effective staggered-grid source-receiver survey design was implemented, with the goal of improving spatial sampling without incurring the need for more equipment or increased operational complexity (Chandola et al., 2014). In this work, we show the effect of the surface grid on seismic processing and imaging and illustrate seismic data processing techniques to improve surface coverage further to overcome the acquisition limitations efficiently.

Survey Geometry
The survey geometry was oriented north-south for receiver lines, and east-west for source lines. The nominal spacing between receiver lines was 300 m and 250 m for source lines, whilst the receiver interval was 50 m and the source point interval was 25 m. Water depths within the survey area ranged from 8 m to 50 m (Figure 1).
An innovative staggered grid source plus receiver layout was implemented within the development area. The goal was to increase spatial subsurface sampling from 12.5- x 25-m bins within the exploration areas, to 12.5 m x 12.5 m within the developmental areas without incurring additional acquisition cost. This staggered design was coupled with denser source line spacing in the developmental area to improve the coverage fold and near-offset distribution.
Mechanical Damage Characterization in Proppant Packs Using Acoustic Measurements
Authors: Aderibigbe Aderonke Abiodun , Valdes Clotilde Chen , Heidari Zoya , Fuss Tihana 
Published: March 2015

Abstract
The strength and conductivity of proppant packs are key parameters for assessing their performance. Mechanical damage in the propping agents, leading to compaction and crushing, significantly reduces the conductivity of the proppant pack. Mechanical damage of proppants is usually analyzed using crush tests. However, measurements from these tests remain questionable because of discrepancies in procedures and test results. Therefore a need emerges to develop techniques for characterizing the properties and mechanical damage in proppant packs.
In this paper, we introduce a new technique based on interpretation of acoustic measurements to quantify mechanical damage in propping agents. We performed uniaxial compression tests in the laboratory and measured the compressional- and shear-wave velocities in proppant packs loaded at axial stress ranging from 10 MPa to 110 MPa. After unloading the tests in which maximum axial stress of 28, 55, 69, 97 and 110 MPa were applied, we conducted sieve analysis on the proppant packs. We applied an effective medium theory based on the Hertz-Mindlin model to approximate the effective elastic properties. We then calibrated the model using the elastic properties estimated from the experimental measurements to characterize the mechanical damage of the proppant packs.

Introduction
Proppants are used to create conductive pathways for reservoir fluids by keeping the created fractures propped open in hydraulic fracture stimulation treatments. The application of proppants in stimulation treatments is largely influenced by properties such as permeability, conductivity, and resistance to crush. The reduction in fracture conductivity is usually associated with proppant failure and fines migration. The failure of proppants can occur as a result of geochemical reactions and/or mechanical damage.
An Innovated Approach for History Matching by Reliable Fracture Modeling - Case Study of NKJ Gas Field
Authors: Ben Amor Faical , Amari Mustafa , Sharifzadeh Najafi Ahmad , Dashti Qasem , Al-Saffar Ali 
Published: March 2015

Introduction:
The North Kuwait Jurassic Complex (NKJC) is composed of six fields and situated in the Northern part of Kuwait (Figure 1). The field is characterized by dual porosity/permeability in deep HP/HT conditions, with wide variety of hydrocarbon fluids ranging from volatile oil to gas condensate. The primary recovery mechanism and the recovery efficiency strongly rely on fractures. Therefore, reliable and calibrated fracture model is required in getting a representative dynamic model.
Using a wide range of 2D/3D seismic, geometrical and petrophysical attributes, a hybrid natural fractured reservoir static geomodel, made of Discrete Fracture Network (DFN) and Implict Fracture model (IFM), has enabled a reasonable 3D representation of three sets of fractures, identified based on well and seismic data:Fracture corridors associated to geophysically interpreted faults;Medium scale layer bound geomechanically controlled fractures; andFolding related fractures.
The new hybrid fracture model was calibrated using PLT, MDT and PBU data from more than 60 wells drilled in the reservoir.
This paper demonstrates how a calibrated hybrid fracture model has shortened the process of the history match significantly, which required only very small adjustments/alterations to the initial static model. The uncertainty and the challenges faced while calibrating the model were addressed, together with the highly sensitive parameters that were adjusted to match the dynamic data. Succeeding a smooth and timely history match resulted in significant CPU time gain, and an optimized well count that went into the Asset Action Plan.
History and Evolution of the Product Selection Criteria for Selecting Kinetic Hydrate Inhibitors
Authors: Jardine Joanne , Jackson Steven , Longfield Joanne , Cook Stuart Edward , Smith Christina 
Published: March 2015

ABSTRACT
Gas hydrate formation and control is a critical flow challenge that many offshore oil and gas production operations encounter. Formation of hydrates can cause blockage of production flowlines, chokes and valves, which can result in catastrophic failures. Compared to other production problems, hydrate formation is a relatively new phenomenon that is becoming more and more significant with increasing subsea and deepwater developments as well as huge gas projects in the Middle East. The use of low dosage hydrate inhibitors (LDHIs), such as kinetic hydrate inhibitors (KHIs), offer an alternate technical solution to thermodynamic hydrate inhibitors by offering better economics, improved Health, Safety and Environmental (HS&E) performance and less demand on product transportation and storage.
This paper summarizes the history, evolution and current state of KHI laboratory testing requirements. Improvements in laboratory techniques to evaluate the performance of KHI in sweet and sour environments will be discussed. The results of the evaluation are based on laboratory conditions and the ability of a KHI to successfully inhibit hydrate formation in sweet and sour rocking cells. Recent testing has shown significant differences between sweet and sour environments and the ability of the KHI to successfully inhibit hydrate formation under laboratory conditions.
The secondary properties of a selected KHI are becoming more important so are advances in evaluating these properties, in particular the stability and applicability of a KHI under proposed system conditions. Hydrates may form different structures depending on the gas composition of the produced fluids. The nature of the KHI used needs to take into consideration. Recent product developments in this area show that these challenges can be met with appropriate lab testing.

INTRODUCTION
Flow assurance is critical during the efficient production of hydrocarbons from offshore and subsea assets. Gas hydrate formation and control is a critical flow assurance challenge that many offshore oil and gas production operations encounter. The interaction of low-molecular weight gases such as small chain hydrocarbon, and acidic gases like carbon dioxide and hydrogen sulfide, with water under "high" pressure and "low" temperature within a pipeline can form gas hydrates. Gas hydrates are essentially a gas molecule encapsulated by water molecules which have an ice like appearance. Two types of hydrate structure form in gas pipelines, type II being the most common and associated with larger gas molecules such as ethane and propane and type I mainly associated with lean gas and/or carbon dioxide or hydrogen sulfide production. Gas hydrate crystals may agglomerate and/or anneal to form plugs that results in lost production and may incrase (HS&E) risks. Formation of hydrates can cause blockage of production flowlines, chokes and valves, which can result in potentially catastrophic failures.
Verification of the hydrocarbon accumulation in the fault leaned closure with small fault throw: Case study for the Late Miocene Deltaic Sandstone Reservoirs (Sarawak Cycle V) Block D, Sarawak, Malaysia
Authors: Uchimura Ryuichi , Yoshikawa Kosuke , Adian Syafiza , Terabe Kazunobu , Yasukochi Toru , Chin Pei Tze , Yii Chiu Jin 
Published: March 2015

Extended Abstract
An exploration well was drilled into a fault-lean 3-way-dip closure along the proven Miri-Rasau anticline. The trapping fault has the largest throw in its central part and dies out laterally and downward. However, we discovered 350m of net hydrocarbon column in six thick sandstones trapped only by the lower part of the fault where its throw was minimal. The throw at the deepest discovery is not clear on seismic but is recognizable only by bends of seismic events. Since the fault throw is smaller than the sandstone thickness, extensive sand to sand juxtaposition is expected unless there is a continuous clay smear. This study aims to evaluate the mechanism of fault trap using available quantitative methods.
New 3D seismic data acquired after the discovery was interpreted in detail around the fault block and careful editing was made for depth converted maps to establish the detailed framework model. A lithology (Vsh) model was also established based on well/seismic data utilizing a geostatistic method.
First, juxtaposition across the fault was identified based on the 3D model. Second, quantitative fault sealing capacity analyses for Shale Gouge Ratio (SGR) and Shale Smearing Factor (SSF) were performed along individual fault planes using fault throw and Vsh at each cell using Structural and Fault Analysis (RDR) module in Petrel (Schlumberger TM). Third, the SGR model was then converted to a maximum potential hydrocarbon-column height (HCH).
Designing a Business Transformation Strategy for Integrated Operations
Authors: Dawam Abdul Ghaffar , Wong Fadhli , Bonilla Juan Carlos Gonzalez 
Published: March 2015

Abstract
PETRONAS Carigali Sdn Bhd has embarked on a journey to incorporate Integrated Operations (IO) concepts as a standard way of working across their production business. Early on it was identified that the implementation of IO as a core enabling element within the production business would create a fundamental change in operations - transforming decision-making from a mechanical process to an organic capability by embedding a culture of collaboration as the basis of an asset's Operations Philosophy (i.e. an asset mindset operating within a functional organization). This fundamental change would require visible leadership in addition to the management of incremental implementation steps: a combined top-down, bottom-up approach.
Further, there would be long term structural transformation due to: scale (the change affects multiple assets not only individually but also collectively with significant implications to the rest of the organization), magnitude (it will involve significant alterations to information availability, capability, and decision-making processes), duration (implementation will span a number of years), and strategic importance to PETRONAS' future business.
Consequently, a comprehensive IO business transformation strategy was required, based on an in-depth understanding of what the implications of the various asset-level digital field solutions are for the organization as a whole, as well as individual stakeholders, driving a plan customized to optimally lead the adoption effort through tailored interventions by business unit, location, role, function, and decision-making patterns.
This paper will review the specific implications of IO within the organization and present how a business transformation strategy was developed to optimally manage the consequences, while mitigating the risks to success.

Executive Summary
The following statements form the basis of the IO transformation strategy and implementation plan:Implementation of IO will create a fundamental change in operations by:a.Transforming decision-making from a mechanical process to an organic capabilityb.Enabling new opportunities for extending field life, improving recovery factor, empowering HSE and optimizing productionc.Embedding a culture of collaboration at the core of an asset's Operations Philosophy: an asset mindset operating within a functional organizationd.Addressing organizational challenges between central office and field personnel
Long-term outcomes in primary spinal osteochondroma: a multicenter study of 27 patients
Authors: Sciubba Daniel M. , Macki Mohamed , Bydon Mohamad , Germscheid Niccole M. , Wolinsky Jean-Paul , Boriani Stefano , Bettegowda Chetan , Chou Dean , Luzzati Alessandro , Reynolds Jeremy J. , Szövérfi Zsolt , Zadnik Patti , Rhines Laurence D. , Gokaslan Ziya L. , Fisher Charles G. , Varga Peter Paul 
Published: March 2015

OBJECT
Clinical outcomes in patients with primary spinal osteochondromas are limited to small series and sporadic case reports. The authors present data on the first long-term investigation of spinal osteochondroma cases.

METHODS
An international, multicenter ambispective study on primary spinal osteochondroma was performed. Patients were included if they were diagnosed with an osteochondroma of the spine and received surgical treatment between October 1996 and June 2012 with at least 1 follow-up. Perioperative prognostic variables, including patient age, tumor size, spinal level, and resection, were analyzed in reference to long-term local recurrence and survival. Tumor resections were compared using Enneking appropriate (EA) or Enneking inappropriate surgical margins.

RESULTS
Osteochondromas were diagnosed in 27 patients at an average age of 37 years. Twenty-two lesions were found in the mobile spine (cervical, thoracic, or lumbar) and 5 in the fixed spine (sacrum). Twenty-three cases (88%) were benign tumors (Enneking tumor Stages 1–3), whereas 3 (12%) exhibited malignant changes (Enneking tumor Stages IA–IIB). Sixteen patients (62%) underwent en bloc treatment—that is, wide or marginal resection—and 10 (38%) underwent intralesional resection. Twenty-four operations (92%) followed EA margins. No one received adjuvant therapy. Two patients (8%) experienced recurrences: one in the fixed spine and one in the mobile spine. Both recurrences occurred in latent Stage 1 tumors following en bloc resection. No osteochondroma-related deaths were observed.

CONCLUSIONS
In the present study, most patients underwent en bloc resection and were treated as EA cases. Both recurrences occurred in the Stage 1 tumor cohort. Therefore, although benign in character, osteochondromas still require careful management and thorough follow-up.