bluuebunny/crossref_metadata_2025_split huggingface dataset:
A Novel Approach for Estimating Continuous Matrix Permeability with Open-Hole Capture Spectroscopy Logs and Formation Pressure Tests
Authors: Guo Shusheng , Chen Jianghua , Gao Yongde , Li Ting , Shim Yen Han , Zhang Lei 
Published: March 2016

Abstract
For most conventional reservoirs, matrix permeability determines the rock's ability to transmit fluids. It is a crucial input for the operator's completion design. Unfortunately, direct measurement of permeability is hard to obtain through well logging. Traditionally, a continuous permeability log is estimated from other petrophysical properties derived from well logs, such as porosity. The porosity-to-permeability relationship is typically established from core measurements. The drawback of this method is that porosity alone is insufficient to characterize the full variability in permeability. Also, the application of this method is limited by availability of core measurements representative of the reservoir in question.
In this report, we examine a siliciclastic oil reservoir in South China Sea with interbedded sandstone and shale. In such reservoirs, heterogeneity in permeability exists at a small scale. In order to capture the full variability of such reservoirs, it is critical to obtain a continuous permeability curve of the rock matrix.
It has been shown previously that permeability can be accurately computed from surface area-to-pore volume ratio (k?). This ratio can be obtained from lithology weight fractions by associating a specific surface area (S0) with each lithology. In general, the S0 values for clean sand and carbonate are well defined and stable. However, S0 for clay depends largely on clay type and varies from sample to sample. Since clay has the most significant effect on permeability, it is critical to select the correct k? for clay in the model.
In modern logging programs, formation pressure tests are commonly included for reservoir characterization. By observing pressure behavior versus time in a pretest, one can obtain direct measurement of fluid mobility at discrete stations along the well. This mobility can be converted to permeability if fluid viscosity is known. We can then use these measured values to calibrate clay S0 in our permeability model. Here is the workflow:
Zone the well such that the clay type is consistent within each zone.
Using a univariate optimization routine, find the clay S0 that minimizes the difference between k? and permeability from pressure tests.
Plug the calibrated S0 for clay into k? model to compute a continuous permeability log.
The above method was validated using a set of LWD logs acquired while drilling and LWD pressure tests acquired while reaming.
Drilling Fluid Density Calculation Model at High Temperature High Pressure
Authors: Peng Qi , Fan Honghai , Zhou Haobo , Liu Jinge , Kang Bo , Jiang Wenlong , Gao Yuan , Fu Suiyi 
Published: March 2016

Abstract
Drilling fluid density is very sensitive to the variation of temperature and pressure, especially in deep water and high temperature/high pressure environment. As downhole environment is different from the environment at surface, there must be a difference of density under these two conditions. The accuracy of downhole density calculation is directly related to whether the true downhole hydrostatic pressure could be reflected or not. Drilling fluid could be compressed under high pressure as well as be expanded under high temperature conditions. This paper proposes two important relational equations based on isothermal compressibility and isobaric expansivity. One equation is the relationship between isothermal compressibility and pressure. In this case fluid's volumetric reduction under certain pressure increment could be obtained. The other equation is the relationship between isobaric expansivity and temperature. Similarly, fluid's volumetric increment with the increasing temperature could be gotten by this equation. Therefore the true hydrostatic pressure at downhole could be accurately described by solving these two equations. Experiment data results show that curves of isothermal compressibility with pressure and isobaric expansivity with temperature are both conformed to exponential form. Besides, there is a special set of temperature and pressure for a given drilling fluid. Under this special situation, the compressibility are exactly offset by thermal expansivity, then mud density remain unchanged. Field applications indicates that this density model can describe downhole hydrostatic pressure well at Northwest China and South China Sea. Through adjusting mud density by this model, the headache problem of shallow narrow mud density window formation at South China Sea is well overcome. In addition, the true downhole equivalent static density (ESD) is smaller than fluid density measured at surface in a HP/HT well of Northwest China, whereas the situation is just the opposite in a deepwater well at South China Sea. Undoubtedly, the analysis of downhole hydrostatic pressure is a key process in drilling engineering operations. Too often, failure to accurately monitor wellbore ESD can lead to high risk activities, such as excessive well costs and unscheduled trouble time. Consequently, the HT/HP density model proposed in this paper, which provides an effective way to deal with those problems, is worth applying and promoting.
Comparison between Quasi-Static Analysis and Dynamic Simulation for the Motions and Mooring Tensions of Floating Offshore Platforms
Authors: Lim D. , Kim Y. , Park B. 
Published: March 2016

AbstractAs the development of offshore oil well advances to deep sea, the platform/mooring lines coupled analysis in time-domain is required in estimating the design tension to consider the complex nonlinear effects in the dynamic responses of floating offshore structures. However, in the early design stage where a number of environmental conditions are dealt with, a simpler analysis method adopting the uncoupled and quasi-static analysis is still practical. In this study, the uncoupled, quasi-static analysis in frequency-domain and the coupled analysis in time-domain were compared to establish a basis of design analysis flow from former to latter. A semi-submersible platform was selected as a comparison model, and a reasonable agreement between the two analysis methods were identified.
Cost Saving of Implementing Virtual Flow Metering at Various Fields and Engineering Phases - A Case Study
Authors: Varyan R. 
Published: March 2016

Abstract
Many companies are actively seeking alternative ways to develop a new field and/ or extend the production of mature fields at lower cost during the current downturn in the oil and gas industry. Numbers of advanced technologies are considered to change the conventional way of developing fields such that Capital Expenditure (CAPEX) and Operational Expenditure (OPEX) can be minimized. One area of improvement is flow metering. Having the ability to monitor individual well flow rates continuously allows the operator to optimize the production and maximize the uptime. Traditionally this has been achieved by installing a multiphase flow meter on each well. For some fields, this option is not feasible mainly due to the initial cost.
Combining the simplicities, robustness, and low cost, Virtual Flow Metering Systems (VFMS) address those needs to provide operators an alternative flow metering solution. VFMS have been known as an alternative low cost flow metering solution that is being implemented and the benefits realized in the global oil and gas industry. Notwithstanding the technology has been in operations for more than 20 years in some regions, mainly in subsea production system, the capabilities and dependencies of this technology remains unfamiliar to many, particularly in Asia Pacific region.
Case studies have been performed to assess the benefit of implementing VFMS at both subsea and surface production systems at different phases of field life. Potential saving on CAPEX is observed to be the highest when the flow metering solution has been considered since the early stage of engineering phase in green field subsea project (numbers of area for optimization is foreseen along with the estimated cost-saving). Implementation of a VFMS in brown field project can be done seamlessly and therefore eliminates the need of piping work and production shutdown.
The Design and Deployment of Open Hole Standalone Screens and Two Cased Hole Gravel Pack in Highly Deviated Well—A Case History with A Field in Malaysia
Authors: Ab Rasid Mohd Fakhrin , Mohd Zain Siti Nur Mahirah , Osuji-Bells Godwin Akujobi , Samuel Orient Balbir , Zabala Jose , Zainal Abidin Mohd Reduan , Noorizan Airin Basha , Gil Joel 
Published: March 2016

Abstract
This paper summarizes the challenges faced during the well completion design, planning and execution stages in the "Well-B" located on the "Field-A" offshore Malaysia. In addition, it highlights the modifications and techniques incorporated in the completion design to ensure that the well was delivered flawlessly in terms of HSE and quality.
At the initial planning stage, the proposal on this well was to complete two oil producer sands with active sand control methods, the upper zone with Cased Hole Gravel Pack (CHGP) and the lower zone with Open Hole Standalone Screens (OHSAS), this concept changed after the analysis of the logging while drilling (LWD) output, when the subsurface team decided to complete an additional zone (midzone) with a stacked Cased Hole Gravel Pack.
The well completion operation effectiveness on this well could have been affected by the following challenges: High deviationMultiple sand control techniques in one wellOperation and logistic challengesAdditional zone expected to be completed with the available inventoryLimited resources and time
The team incorporated several techniques into the original completion design to enable the effective execution of these three zones and achieving the overall well objective.
After the well was successfully completed, it became the first highly deviated well in the field with an open hole standalone screens in the lower zone and two cased hole gravel pack in the upper zones with a dual upper completion string.
This well completion will become the benchmark for planning, designing and deploying future wells with similar characteristics and reservoir conditions.
Ultrabroadband Acoustic Logging Tool for Deep Reading Formation Evaluation
Authors: Sun Baichun , Wang Ruijia , Li Wei , Jonathan Brenda Sue , Langley Bill , Wilson Glenn , Cheng Arthur 
Published: March 2016

Abstract
This paper introduces an ultrabroadband array sonic logging tool and related processing for wireline logging in both open and cased holes. The tool consists of six broadband monopole and dipole transmitters and 104 highly sensitive wideband receivers, enabling deep-reading formation evaluation in axial, radial, and azimuthal directions around the tool.
The transmitter drive pulses from the six broadband monopole and dipole transmitters are dynamically optimized and controlled to cover a large dynamic range in formation slowness. The low-frequency monopole source is designed for measuring Stoneley dispersion curves. A high-frequency monopole source array helps enable extraction of compressional slowness and arrivals that can generate enhanced radial compressional slowness profiles. These deep readings are then used to evaluate the formation in three directions around the sonic logging tool.
The orthogonal dipole sources help enable direct measurement of the shear slowness from the low-frequency flexural asymptotes without the need for dispersion correction. Real-time processing, including quality control of transmitter and receiver sensitivities, delivers high-quality compressional, shear, and Stoneley wave slowness. Subsequent post-acquisition answer products include formation compressional and shear slowness, shear anisotropy, and Stoneley reflections and permeability. Further interpretation of low-frequency compression waves helps enable measurement through high attenuation gas zones and also measure the true formation compressional slowness in very slow formations where leaky compressional modes are prominent. Also, shear slowness measurements through very slow formations allow improved seismic ties from mudline to depth.
This next-generation ultrabroadband array sonic logging tool allows for deeper reading and more comprehensive formation evaluation in cased and open holes. In addition to discussing the process for using the tool in wireline logging, this paper provides examples for logs of both slow and fast formations.
Journey to Success - Advancement of Coiled Tubing Drilling in Malaysia
Authors: Ooi Zhon Wei , Hamzah Nurul Ezalina , Ibrahim Zahidi , Fauzi Nurfaridah Ahmad , Pozdnyshev Maxim 
Published: March 2016

Abstract
Coiled Tubing Drilling (CTD) Technology was first implemented by Petronas Carigali Sdn. Bhd. (PCSB) in 2011 where 3 wells were successfully drilled via a pilot campaign. The rig-less technology allows through-tubing side tracking to be conducted from the existing completion. This approach provides access to marginal bypassed reserves, which otherwise would be uneconomical to be developed by conventional drilling. The entire project comprised plug and abandonment work, whipstock setting, window milling, drilling of the build & lateral sections and completion as per the well design.
The second phase of CTD project was successfully executed from June to December 2013 with all the three wells successfully drilled and completed as per the objectives. Different from pilot project modus operandi, Self-Elevating Workover Platform Vessel (SEWOP) also known as liftboat was utilized to assist the operation due to limited space and deck loading on the working platform. Such approach has minimized the platform modification required as well as significantly reducing the dependency of on good weather window. The self-propelled SEWOP option has proven to be a self-sufficient by providing the required deck space, accommodation and a stable platform in allowing the CTD operation to be carried out safely.
Highlights of the project was the successful drilling and completion of the world's first CTD multilateral well. Such strategy involved the drilling and completion of two separate targets from one mother bore with dual completion strings. In order to achieve the well objectives, the team was challenged with complicated well preparation work scope such as multiple stages of cementing job and accurate determination of the azimuth of the dual kick off points from the existing dual completions in order to avoid drilling collisions during side-tracking.
In addition, team has also managed to replicate the lessons learnt from the pilot project with 100% success rate in dual casing exit from the existing completion setup as well as conveying the completion to the target zone via CT through 3½" tubing with maximum inclination of 90 deg angle and dogleg ranges between 20–40 deg per 100 feet.
The second phase project utilized Reservoir Navigation System (RNS), Managed Pressure Drilling (MPD) and Rotary Steerable Motor (RSM) that optimized payzone drilled, improved drill-ability and smoothened long trajectory thus improving operational efficiency and success rate.
Despite multiple challenges, the project was able to be completed safely and successfully with all objectives met. The achievement was largely attributed to good teamwork, visible leadership, and constant support from management and effective communication between project team and service providers.
This paper discussed about the experiences, learning curves, challenges and lessons learnt of PCSB in making CTD technology viable and successful in offshore Malaysia.
The Zipangu of the Sea Project Overview: Focusing on the R&D for Simultaneous Deployment and Operation of Multiple AUVs
Authors: Kim Kangsoo , Tamura Kenkichi 
Published: March 2016

Abstract
This paper presents the overview of a R&D project "Zipangu of the Sea", focusing on the sub-R&D project supervised by National Maritime Research Institute of Japan. Consisting of 7 sub-projects, main object of the Zipangu of the Sea project is the development of core technologies required for exploring, investigating, monitoring, protecting, and developing benthic mineral resources. The project is a collaborative R&D conducted by national institutes, universities, and private companies in Japan. The NMRI of Japan leads a sub-R&D project of developing the system and strategy for simultaneous deployment and operation of multiple AUVs. In this sub-project, AUVs play a leading role as a cutting-edge undersea probe. Supervised by an USV, multiple AUVs form a fully-autonomous undersea survey unit. In this paper, we introduce a new benthic resource survey system consisting of multiple AUVs and an USV being developed by R&D association led by NMRI. Key technologies as well as hardware elements consisting of our system are also overviewed.
Downhole and Surface Vibration Measurement
Authors: Gao Wenkai , Dou Xiurong , Jia Hengtian , Peng Hao 
Published: March 2016

Abstract
Vibration measurement while drilling is very important. Real-time analysis of the vibration data can be used to evaluate the performance of the downhole tools and to identify the rocks. The paper briefly introduced the work principles, composition and application of the system.
The system is composed of near-bit vibration measurement tool, surface vibration detecting device, wireless transmitting system, signal processing and indicating software system. The downhole measurement system detects and processes the near-bit data, the result is sent to surface in real time, then operators can change drilling parameters in time if harmful downhole conditions are indicated, considering with the surface measurement.
This system has been extensively tested and proved to be effective in identifying the difference of breaking fossil coal and other rocks. Detail of the test and the method will be discussed in the paper. Especially in CBM drilling, the conventional electromagnetic resistivity or gamma measurement while drilling system mounts far away from the bit(more than 7m), however the ROP of CBM drilling is usually high, which lead to time lag and large deviation of trajectory. The use of near-bit and surface vibration measurement while drilling system can identify the seam top or floor as quickly as the bit contact the boundary, to increase drilling efficiency.
With the vibration measurement while drilling tool, the drilling efficiency can be remarkably improved. This paper will highlight the technical development and present helpful case histories and recommendations.
Mitigating Corrosion Under Insulation in a Gas Processing Facility 10 Years On
Authors: Biddle Ben 
Published: March 2016

Abstract
As is often the case when developing new technologies the first adopters are those who have a specific problem for which they are seeking a solution. This was the case in 2005 with a new, at the time, high temperature protective coating designed for use beneath insulation and in highly aggressive cyclic temperature environments between 40°C (104°F) to 260°C (500°F). The facility in question is a gas processing plan in South Australia and they had significant issues with corrosion on their propane treater units. This paper will review the circumstances of the application in 2005, detailing the corrosion mechanisms at work and the justification behind the selection of the then largely unproven new coating technology. It will then review the performance of the material over the course of its ten year service life concluding with a detailed review of its current condition. The paper then moves to the wider topic of coating development and specification with particular reference to developing test methods where robust methods are not yet known. The paper details the methodology used to create and validate a reliable test for coatings used in the prevention of CUI. With reference to the South Australian experience, the paper poses the question ‘how can new coating technologies be successfully developed and launched into a such a conservative market?', especially given the importance placed by customers around long term proof of in service performance.
Riser Support Structure for Support of Flexible Risers and Umbilicals
Authors: Rayappa J. W. , Christensen L. 
Published: March 2016

Abstract
Mid-water arches are often used for supporting flexible risers and umbilical's from floating structures onto seabed. If the structure needs to support a number of flexible risers and umbilicals located at a site which is prone to soil liquefaction during seismic conditions, then the selection of an appropriate foundation system and designing the super structure to suit the ground condition becomes a challenge and it is the behaviour of the foundation system that dictates the design of the structure.
The Ichthys Field located about 220 kilometres offshore from the NW coast of Western Australia in average water depths of 250 m is such a site. The Ichthys LNG Project Field development includes a large subsea Riser Support Structure (RSS) supporting up to 25 flexible risers and umbilicals in a "Fixed-S" configuration as they transition from the seabed to the semi-submersible Central Processing Facility. The RSS consists of two key components, namely a 130 m long arch structure and a steel tower with a suction foundation base. The total height above seabed of the RSS is 110 m with a total weight of 7300MT in air. The RSS has been conceptualized to suit the design, fabrication, installation and inplace operations. The RSS was installed using the conventional method of launching at site, self-upending and crane assisted lowering onto the seabed with a controlled flooding of tower legs and Auxiliary Buoyancy Tanks (ABT). The tower is anchored permanently to the seafloor by suction cans.
The objective of this paper is to present the key aspects of the concept and detailed design development of the RSS, including the innovative approach to the environmental and seismic conditions to avoid problems with due consideration of fabrication, transport and installation. The scope of this paper is limited to the RSS structure and will not cover the detail geotechnical foundations design aspects which are the subject of another paper.
Complex Subsea to Subsea Pigging Operations of Pipelines
Authors: Nesje P. 
Published: March 2016

Abstract

Objectives/Scope
Operators of subsea pipelines sometimes find advantages in performing subsea to subsea pigging operations. This type of pigging may be necessary in order to facilitate a specific field layout or concept. However, operational pigging and inspection pigging from subsea pig launchers to subsea pig receivers can create several design and operational challenges. These are identified and addressed in this paper.

Methods, Procedures, Process
Two main types of pigging operations are identified.
The main challenges are:

Results, Observations, Conclusions
The methods and the solutions that we have chosen to use in recent projects are described. The background information leading up to the decisions and choices taken will be discussed.
Special focus will be given to the importance of planning for any subsea operational and/or inspection pigging up front in the field layout and design phases, i.e. at the same time as the commissioning pigging is defined.
The need for a reliable and safe pig tracking management system will be addressed and our observations with respect to this issue will be included.
The specific advantages for the Subsea Automated Pig Launcher will be highlighted, a short list of these are:

Novel/Additive Information
This paper will present practical and sound solutions of how to perform subsea to subsea operational and inspection pigging in a cost effective and safe manner.
It will also highlight and explain the importance of planning for any subsea operational and/or inspection pigging up front in the field layout and design phase. This is often not a high focus element and this can result in very costly modifications later in the field life.