bluuebunny/crossref_metadata_2025_split huggingface dataset:
Management of Well Integrity Across Divested Upstream Assets
Authors: Spowage A. C. , Copping S. , Lunt G. , Bhardwaj J. , Smith C. , Smith L. 
Published: March 2018

Abstract
The recent lower for longer environment within the Oil and Gas industry has resulted in a wide range of challenges for operators. One of the responses has been to increase the pace of divestment of mature assets from large operators to independents. The objective of this work is to distill the lessons learned through the implementation of well integrity management systems across the globe. The work focuses on those aspects of the process that are of particular relevance to mature divested assets. The methodology used is to focus on the drivers and specific challenges new operators face and then distil the key points into a simple implementation process.
A four step implementation process has been developed: Data and System Audit, Well Integrity Management Manual, Central Well Integrity Management Software Solution and Engineering Support services. Within each step the challenges are addressed within the narrative of the various steps and the lessons learned through implementation experience are outlined. The requirements of the applicable standards were extracted and found to include the management of: Operating Limits, Performance Standards, Barriers, Annulus Pressure Management, Well Monitoring and Surveillance, Well Maintenance, Management of Change, Risk Assessment Process, Well Handover and Well Integrity Reporting.
The paper aims to provide practical guidance which can be used to assist those who may face similar challenges in the future.
Drilling Fluid Impact Studies Show that Worker Health and the Environment Can Be Protected While Improving Drilling Performance
Authors: Lim Serena , Lyon Delina , Whale Graham , Lee Burnell , Boogaard Peter , Grover Pat , Slyke Don Van , Koh Jane , Abd-Rashid Azman 
Published: March 2018

Abstract
GTL (Gas-to-Liquid) drilling base fluids, such as Shell GTL Saraline™ 185V/NEOFLO™ 4633, are synthetic hydrocarbons produced via Fischer-Tropsch synthesis from natural gas. GTL Fluids are predominantly comprised of iso- and normal paraffins and contain virtually no aromatics or contaminants such as sulphur and amines. Saraline 185V is a Health, Safety, Security, and Environmental (HSSE)- advantaged base fluid for use in global exploration and production drilling operations onshore and offshore.
Extensive terrestrial, freshwater and marine ecotoxicity testing with Saraline 185V and related GTL Fluids confirm a lack of acute or significant chronic toxicity to a wide range of environmentally relevant organisms. Saraline 185V is also readily biodegradable in aerobic freshwater, seawater, soil and sediments and will also degrade under anaerobic conditions. The biodegradability can be exploited to bioremediate drill cuttings, as has been demonstrated in both laboratory and field trials. Furthermore, when used offshore, marine benthic surveys have demonstrated that degradation also occurs and that there is a lack of any significant environmental impact associated with the discharge of Saraline 185V contaminated drill cuttings.
Extensive mammalian toxicity testing of GTL Products indicates that Saraline 185V will exert very little, if any, toxicity in mammalian species. Saraline 185V is odourless, and vapour emission tests reveal that it has &gt;7-fold lower gas emissions when compared to conventional diesel, thereby leading to better air quality on drilling locations. A recent study which assessed emission and personal exposure levels to various hydrocarbons at key phases of drilling operations confirmed that significantly lower hydrocarbon exposures occurred for mud systems based on Saraline 185V compared to conventional diesel.
The drilling performance of GTL versus diesel based muds has also been assessed in an onshore drilling operations study. To enable a fair comparison all wells were drilled in the same formation (located in the Permian Basin of West Texas) using the same drilling rig, crews, bit, footage, fluid contractor, tools and directional driller. These field trial data indicated an overall drilling improvement for GTL over diesel mud.
This paper provides an overview of the exposure, human health, environmental and performance studies conducted on GTL drilling fluids. In combination, these create a value proposition for GTL Fluids showing that better health management combined with reduced environmental footprint and improved drilling and equipment performance leads to lower total well costs.
Impact of Data Reconciliation at Various Scales in the Construction of Reservoir Model
Authors: Murugesu Thanapala S. , Masoudi Rahim , Wibowo Suryadi , Grippo Nicolas , Johare Dzulfadly B. , Marzuki Izral Izarruddin B. 
Published: March 2018

Abstract
Reservoir model is widely used in oil and gas industry for hydrocarbon resources assessment, development, and management with different depletion strategies. The reservoir model is built through integration of multi-disciplinary information, data and interpretation at various scales. Integration of data from various resolutions and scales is usually a big challenge in constructing reservoir model due to its impact to the model's ability to make a reliable production forecast. The objective of this study is to analyze the impact of scale changes in clastic reservoir modelling and to evaluate its implication to hydrocarbon volume in-place and fluid flow behavior. Several examples from clastic reservoirs of different geological environments were evaluated and data from various scale were incorporated in reservoir description in constructing a representative reservoir models. Reconciliation of various reservoirs properties using database such as core data, logs, DST and production/pressure were performed.
Permeability upscaling was observed posing significant challenges compared to the other properties at each stage. Therefore, the paper puts more emphasize on permeability while briefly discuss the other properties. Other challenges including complex reservoir types such as thinly laminated reservoirs are also evaluated. The study demonstrates that different permeability modeling methods may give significant impact on the hydrocarbon in-place and fluid flow characteristic. In the absent of production data to verify the in-place, the uncertainty of in-place is inevitable. In addition to that, those different permeability models may also give different flow characteristic.
It is concluded that by recognizing the scale difference and impact of averaging/upscaling with the guidance from production/pressure performance, robust reservoir model with representative reservoir properties could be achieved. This paper shares the best practices in integrating data from various scale/discipline and highlights the impact of the data integration at right scale in constructing robust reservoir model.
First Successful Deployment of 17-Chrome OCTG CRA Corrosion Resistant Alloy Tubular as Production String in the World
Authors: Johari M Raimi , Jusoh Nur Zulaikar Md , Hong Ong Swee , Fabian Oka , Rashid Noor Hidayah A , Idris Mohd Faisal Rizal , Musa M Zarir , Balbir Orient Samuel , Rosato Miguel , Shaedin Ridzuan , Teng Chaw Kit , Riyanto Latief 
Published: March 2018

Abstract
PETRONAS embarked on a new challenge to drill and complete 5 wells with high bottom hole temperature (BHT) of 180°C and highly deviated fractured carbonate with high velocity gas producers. These wells utilized 7" big bore production tubing with new material 17CR instead of the expensive cold worked 22CR duplex stainless steel (DSS).
As the first application of 17CR production tubing material in the world, a lot of risks were taken into account and mitigated via various approaches from planning engineering stage until execution. These mitigation measures included the qualification of material and connection; operational details involving parties from different disciplines to ensure smooth and efficient deployment of 17CR tubing. In addition to that, optimization opportunities were explored to further increase running efficiency and reducing flat time while ensuring tubing integrity is intact.
The successful deployment of 17CR were attributed to the following: Connection modification from JFE BEAR to JFE BEAR DR-PK to minimize the risk of galling around the metal-to-metal seal area on the newly developed 17CR CRA materialTubing was racked back in double joints per stand offline during installation using offline activity cantilever (OAC) deck available on a tender assisted rig to improve running timeUtilization of side door elevator instead of single joint compensator to enable running tubing in double.Usage of Flush Mounted Slip (FMS) dressed with pre-qualified low penetration dies, to ensure sufficient gripping on the 17CR tubing OD surface without being affected by the surface scale which is known to have with high hardness valueUsage of low penetration dies instead of non-marking type hydraulic tong to reduce tubular running cost
With the above mitigation measures put in place, the project was delivered with high efficiency in terms of tubular running speed achieving up to 14 joints per hour on 7" high alloy CRA tubing with extremely low number of rejection rate (0.3%) for the entire project. Utilization of 17CR as an alternative to 22CR DSS has also contributed direct cost saving of up to USD 8.2 mil to the project.
Subcooling and Induction Time Measurements of Probabilistic Hydrate Formation
Authors: Lim Vincent W. S. , Metaxas Peter J. , Zhen John , Stanwix Paul L. , Johns Michael L. , Aman Zachary M. , May Eric F. 
Published: March 2018

Abstract
The risk of natural gas hydrate formation in oil and gas flowlines increases when production moves into deep-water regions under high pressure conditions. Unlike hydrate dissociation, which is deterministic, the formation of gas hydrates is a well-known stochastic phenomenon which has not been fully characterized to date. Currently, it is often assumed that gas hydrate will form when the subcooling exceeds 3.6 °C (6.5 °F); this value is a heuristic based on limited field-tests. To more accurately predict when and where hydrates are likely to form, large experimental datasets are required to quantify probabilistic hydrate formation. Two generations of High Pressure Stirring Automated Lag Time Apparatus (HPS-ALTAs) were developed to repeatedly measure the formation driving force in term of subcooling and induction time. These HPS-ALTAs are capable of generating statistically significant datasets – typically on the order of 100 formation events – that enable the calculation of formation probability as a function of subcooling from hydrate equilibrium. The current results demonstrate that hydrate formation is strongly dependent on shear, with mean subcooling being reduced by 45% when the mixing speed was increased by a factor of seven. Additionally, initial induction time distributions have been measured at two subcooling values, and are described well by an exponential distribution as expected from theory.
High Resolution Reservoir Parameters, a Novel Approach to Enhance Vertical Resolution of Conventional Logs
Authors: Abul Khair H. , Kantaatmadja B. , Som R. , Baharuddin S. , Goodman A. , Sedaralit F. 
Published: March 2018

Abstract
The ability to detect, evaluate and model thinly laminated formations, as well as to include the sand portion in the reserve calculations, has continuously been a challenging task for oil and gas service and operation companies. This challenge is directly attributed to two reasons:
The big difference between the conventional log's vertical resolution (6 inches and above) and the thickness of these beds (sometimes less than 1 inch); and The direct influence of the low resistivity shale laminations within these thin sand laminae on supressing the resistivity reading (thus masking the existing thin sand laminae, which may be oil prone)
Many efforts in the industry to characterise these thinly laminated reservoirs were put together. Yet, all the existing approaches experience some uncertainty in their results. Most of the industries current approaches contain drawbacks due to certain assumptions involving i thin beds analyses, resulting in high uncertainty. Thus, new technology is needed to improve development and production from these reservoirs.
In this research, wells from 4 fields in both Malay Basin and Sabah Basins, with over 4000 feet of core analysis, full sets of conventional logs and over 5000 feet of different types of micro-resistivity image logs were used. New methodology to calculate true resistivity at a vertical resolution of 0.1 inches was introduced in both oil and water-based mud. A modified alpha processing approach solves the mud influence by introducing a new projecting factor.
New methodology to calculate high resolution density and neuron porosity was also introduced to be used with high resolution resistivity log and to conduct full reservoir evaluation using the high-resolution logs. This includes calculating lithology, porosity, permeability and water saturation at the resolution of 0.1 inch. Calibration of the results with core data and core plug tests supported the findings and showed that the new evaluation using the high-resolution logs is better at matching the core tests than the currently available methods. Thus, this novel approach can be used to evaluate thin beds in any environment and using any type of micro-resistivity images.
A New Rheology Model for Hydrate-in-Oil Slurries
Authors: Qin Yahua , Pickering Paul F. , Johns Michael L. , May Eric F. , Aman Zachary M. 
Published: March 2018

Abstract
Gas hydrates are ice-like solids that can form in crude oil flowlines at high pressure and low temperature; in severe cases, hydrate particles may aggregate in the oil phase and ultimately occlude flow in the line. In order to quantify the risk of plug formation, an accurate universal predictive model for hydrate-in-oil slurries is required. Currently, only one model has been proposed to predict the viscosity of hydrate-in-oil slurries, with an average deviation of 70% from new experimental data. In this work, a temperature-controlled, high-pressure rheometer with a vane blade rotor was deployed to study the rheological properties of hydrate-in-crude oil slurries, which were reacted from water-in-oil emulsions with and without anti-agglomerants (AAs). The results indicate that the addition of AA greatly reduced the viscosity of the hydrate-in-oil slurry, while the slurry maintained shear thinning behavior. The infinite shear viscosity data showed the basis of the current hydrate slurry model is does not appropriately capture the rheological properties of hydrate suspensions. By considering the shape effect of hydrate particles, a new model for hydrate-in-oil slurry has been proposed.
Research and Test of Downhole Measurement Device for Seismic Measurement while Drilling System
Authors: Gao Wenkai , Jia Hengtian , Zhao Hong , Ai Weiping , Zhang Lei , Cao Chong , Hong Difeng , Teng Xinmiao 
Published: March 2018

Abstract
The combination of seismic exploration technology and drilling engineering forms the seismic measurement while drilling (SWD) technology, which can provide conventional borehole seismic measurements in real time while a well is being drilled. Just as conventional while-drilling services, it is effective and efficient in supporting drilling decisions.
With measurement device positioned near the drill bit, real-time processing of downhole seismic data can increase the safety and efficiency to the drilling work. We study the problem in a vertical layered media by using while-drilling measurements, the artificial signal emitted by the seismic source is recorded by surface / downhole sensors, then the direct arrival traveltimes could be obtained after basic data processing. Using the traveltimes as the input of a Bayesian inversion procedure for the estimation of the bit position and the velocity model, the engineers would get the estimated values and their associated uncertainty, which could be used to predict the formation geology ahead of the drill bit and to find the lithology, fracture and abnormal pressure in front of the drill bit in time.
Conventional system has been available to the petroleum industry for some time, with seismic sources located on the surface and receivers in a borehole. The downhole detection device for SWD is mainly composed of three sets of geophone arrays, which are distributed in different axial direction, as well as the corresponding control and processing circuit. We test the inversion strategy on realistic cases in the laboratory and oilfield. According to functions, the electronic circuit is divided into main control and communication unit, signal acquisition unit, storage unit, and power detection & data play back unit. By cross-correlation processing of the direct seismic wave and the reflected waves from formation boundary, the performance of the systems were well proved.
Based on theoretical analysis, system development and experimental study, this paper will highlight the technical development.
Approaching the Superior Management of Explosion Protection Equipment in Mature Field's Hazardous Area
Authors: Kasempong S. , Kanokwareerat N. , Phianloetworakun P. , Sawattanakit N. , Udomsri J. 
Published: March 2018

Abstract
With reference to international standard, IEC 60079-17, each piece of explosion protection equipment shall have their integrity ensured by an initial detailed inspection, and then is to be maintained by periodic inspections at specific times within a 3-year interval.
In the Gulf of Thailand, teams at PTTEP's offshore mature fields put high efforts into performing inspections for more than 200,000 units of Ex protected equipment in accordance with the international standards. However, they are constrained by various factors of the offshore nature e.g. man power, person on board (POB), harsh environment, inspector competency and budget (from the oil price crisis).
To optimize Ex protected equipment inspection, a risk based inspection (RBI) approach as per EI (Energy Institute) recommendation has been introduced since 2016. The end result of this approach would be significant improvement in terms of system integrity and cost effectiveness.
Nevertheless, implementation of new approach in the mature fields is not just a simple plug (in) and play. Key constraints have been proactively identified e.g. lack of a Computerized RBI Ex Protection Equipment Management System, no procedure/ guideline, database incompleteness, etc.
In response to implement successfully RBI Ex inspection, from early 2017, an implementation plan was rolled out to mitigate all issues, especially the computerized system, which is key enabler to RBI Ex inspection; the plan is in-house developed under responsibility of the corporate maintenance team and went go live by November 2017.
This paper provides a description of PTTEP's key initial approaches to this Explosion Protection Equipment Management System, which consists the planning, development, implementation and then up to the improvement phase.
Regional Suitability Mapping PRSM Project - An Update
Authors: Rohani M. J. , Marzuki W. M. , Chan N. , Tho K. K. , Lim L. W. 
Published: March 2018

The PETRONAS Regional Suitability Mapping (PRSM) project was initiated in 2013 with the aim of optimising operational cost efficiency and minimising potential incidents during jack-up emplacement. This project, which is executed as a Consortium Industry Project with PETRONAS Carigali Sdn Bhd (PCSB) as the anchor, and local as well as international consultants as the consortium members, is currently in Phase 2 with Phase 1 being successfully completed in June 2016 ahead of schedule. This paper is intended to discuss the framework of this project, disseminate the key findings and provide an update on the ongoing activities of PRSM Phase 2.
The PRSM project involves integration and analysis of data from various data sources including geotechnical and geophysical site investigation data. These data, which originate from multiple sources, must first be consolidated into a common database before these data can be meaningfully analysed. This is achieved by leveraging on the capability of Geographical Information System (GIS) technology. Data integration and management are key enablers to fully maximise the value of the site investigation data, which were gathered at significant expense. With the data residing in a structured database, an objective hazard analysis framework can be systematically applied to produce a series of individual hazard maps, which are then consolidated into a composite hazard map. The hazard analysis framework, which is established through engagement and consultation with key stakeholders, is efficiently executed using the geo-processing capability of the GIS software.
At the completion of PRSM Phase 1, more than a thousand regional and site-specific hazard maps have been produced. The pertinent conclusion from various stakeholders is that the PRSM project elevates the visibility of a multitude of hazards potentially affecting jack-up emplacement such that these hazards can be pre-empted and managed at an early phase.
This paper will also discuss the steps taken to overcome the challenges of incorporating legacy data, which are of a different standard and format to those commonly adopted today. In order to maximise the completeness of the database, data from as far back as the 1970s were successfully processed and integrated into the common database.