bluuebunny/crossref_metadata_2025_split huggingface dataset:
The Production Benefits of Effective Well Integrity Management
Authors: Smith C. J. B. , Smith L. M. , Spowage A. C. 
Published: March 2016

Abstract
Effective well integrity management (WIM), properly implemented, achieves much more than its core aim of "reducing the risk of uncontrolled release of well fluids to the environment". Wells with ineffectively managed integrity issues result in significant and avoidable levels of well shut-ins and expensive workovers. State-of-the-art WIM software enables evaluation of well data in real-time to identify symptoms of developing issues, and by so doing, also enables proactive steps to be taken to prevent. The outcome is that the need for shut-in or other remedial action is reduced and in some cases sufficient evidence can be provided to confirm that the well is safe to continue in operation.
The same WIM software can also use a real-time risk evaluation to identify the most critical wells requiring specific attention, and in so doing prevent the need for shut-in, or defer intervention safely. The net outcome is that support is given for optimal, right-time decision making – more wells are available for production, risks are minimized (by mitigating problems in the wells with highest risk), and costs are kept to a minimum by prioritizing well activities. Overall production rates are significantly enhanced and overall costs are reduced.
This paper uses a series of examples of the common types of well integrity (WI) issue that can impact production to discuss how the above improvements can be realized. The examples covered in the body of the paper are: sustained annulus pressure, tubing corrosion and scaling. WI issues are also indicators of potentially disruptive production problems in the event of a leak or blow-out. While these risks cannot be fully overcome, they can be mitigated with comprehensive WIM. An observation is made that many WI issues go undiagnosed or undetected and this paper focuses on the importance of data as the input to drive effective monitoring. WI issues have significant potential impacts on production and cannot be treated in isolation. Advanced WIM technology enables the identification and diagnosis of integrity problems and must be considered for production optimization and cost reduction initiatives to be effective.
Unified Thermodynamics and Life of Field in Modelling Complex Upstream Facilities
Authors: Lam Ka-Mun , Zhang Xiaohong , Watson Martin J. , Zhu Wenting 
Published: March 2016

Abstract
Among the hidden and critical challenges in the process modelling of upstream projects are the limitations of compositional capabilities in Integrated Production Modelling (IPM) simulations comprising of complex processing facilities and the inadequacy of steady state and transient state simulations to represent the facilities operability across design life. These challenges become more crucial as future developments are moving to deeper waters and dirtier hydrocarbons.
By implementing Unified Thermodynamics with a single fluid model, MultiflashTM Cubic Plus Association (MF-CPA), all the fluid phases as well as the solid phases such as gas hydrates, waxes, asphaltenes and mercury partitioning can be modelled simultaneously within the IPM itself. The Life of Field (LOF) method enables the understanding of how the different parts of the system in the IPM interact when concepts are changed. The combination of both Unified Thermodynamics and LOF enables front end and operational studies to be performed accurately and efficiently.
The case study shows the impact of two different processing facilities' arrival pressures on the production profile, project scheduling, material selection, gas hydrate formation risk and inhibition requirements, gas compression and turbine performance and sizing, mercury partitioning and CO2 production. By anticipating these changes more accurately, underpinned by MF-CPA, overly conservative equipment sizing can be avoided to reduce project CAPEX and improve asset efficiency across field life. This paper demonstrates the integrated application of process simulation and flow assurance tools from wellbore to customer to optimise project workflows and decision making for optimised investment.
Overpressure Protection Workflow to Address Pipeline Integrity Using Multiphase Dynamic Simulation
Authors: Govindan Gunasekar , Shaharun Azwan 
Published: March 2016

Abstract
This paper proposes a work flow to address the challenges of over pressure in pipelines using the industry standard multiphase transient simulator. Electric submersible pumps (ESPs) are commonly used to increase the productivity of the wells, which, in turn, will generate higher shutoff pressure in the event of sudden wellhead and subsea line valve closures. The topside piping or the subsea line must be protected from overpressure during valve closures with the ESP still in running condition, so that the pressure does not reach beyond the maximum allowable operating pressure (MAOP) of the pipeline. Hence, it is critical to estimate the peak pressure surge, time to reach peak pressure, emergency shutdown (ESD) set point, and high-integrity pressure-protection system (HIPPS) initiation time.
The topside piping is normally designed with an MAOP significantly lower than the ESP shutoff pressure. In the event of sudden closure of wellhead platform valves or the valves located at the end of a subsea pipeline, the pipeline will be pressurized equivalent to the shutoff pressure of the ESP. In general, to protect the topside piping, several layers of protection are provided, with ESD and HIPPS being very common. The proposed workflow demonstrates the use of a multiphase transient simulator to estimate the peak pressure reached upon wellhead valve closure and the time required to reach the peak pressure for different scenarios so that the ESD initiation set point can be selected optimally. Once the ESD sequence activates, the pressure response in the piping during shutdown also can be estimated in an accurate manner. Further, in case the ESD system fails to respond, the workflow identifies the time to activate the HIPPS system, which will be based on the MAOP and time needed for HIPPS to activate. The workflow has been used extensively in major oil projects with ESP-operated wells to address their ESD and HIPPS activation set-point selection as a part of HAZOP closeout.
The workflow underscores the role of transient simulations in predicting the peak pressures, timing, and optimal ESD and HIPPS activation time to protect wellhead piping, thereby providing critical information to address piping/pipeline integrity challenges.
Coring Parameter Optimisation - The Secret to Long Carbonate Cores
Authors: Keith Cheong Ing , Safari Abasad , Aik Khaw Loong , Thanasekaran Maniam , Farouk Mohamed 
Published: March 2016

Abstract
Drilling in carbonate reservoirs are challenging in many ways let alone coring. Recently PETRONAS Carigali Sdn. Bhd. managed to successfully core 224m of carbonate formation in a reservoir which contains 70% Carbon Dioxide (CO2) and 70 ppm Hydrogen Sulphide (H2S). This well is located in the western part of the Luconia field offshore Sarawak in Malaysia.
Core jamming is one of the biggest culprits of failure in obtaining good core recovery especially in carbonate formations. This is due to the highly vugular nature of carbonate formations which also causes losses of drilling fluid. To add to the challenge in this particular field, the carbonates here vary in their degree of porosity according to depth which means a variation of matrix compactness. This causes drilling breaks and can pose a challenge for coring if not understood properly. Core jamming in loose and interbedded carbonate reservoir pay zones has been a frequent occurrence in the wells drilled in these blocks which motivated the drilling team to optimize certain technical aspects of coring such as selectingthe most appropriate core head, bottom hole assembly (BHA), coring parameters and mud system additive chemicals to prevent jamming from happening.
The purpose of this paper is to share PETRONAS' experience of using optimized coring parameters to yield a high percentage of carbonate core recovery. The main advantage of these optimizations is to prevent core jamming problems in the carbonate reservoir in order to obtain good core recovery within the stipulated time. The paper discusses PETRONAS' experience of coring parameters optimization as well as proper coring equipment selection for successful coring in a highly sour carbonate reservoir. On the basis of offset wells and lesson learnt, these optimizations were evaluated and applied successfully to cut the 224m of core in the carbonate reservoir. Several core runs prompted realization that jamming was prone when certain parameters were not optimized hence requiring changes in parameters as well as core bits. Core bit selection and cutter size play an important role in ensuring a successful core run. The understanding of the carbonate reservoir geology is also crucial in order to apply the right parameters to cut the core successfully.
These optimizations proved its worth as it helped PETRONAS to obtain good core recovery and to prevent unnecessary trips that will result in additional time and cost to the operator. This unique PETRONAS experience will help make coring more efficient coupled with good recovery in some of the most challenging carbonate formations.
Structures Deepwater Installation Challenges – North West Shelf, Australia
Authors: Broadway Trent , Tachoires Vincent 
Published: March 2016

Abstract
Today's Oil and Gas developments continue to push the envelope with regard to the increasing weight and size of subsea structures and installation water depth. This paper provides an insight into the challenges encountered and overcome to install 20 subsea structures, some close to 1000Te in weight, and in water depths of up to 1350 meters. The work was for the Chevron-operated Gorgon Project in Western Australia.
Improving the Operational Performance and Reliability of Casing and Tubing With the Use of Dope-Free Connections
Authors: Emiliano Actis Goretta , Mustaffa Merliahmad 
Published: March 2016

Abstract
This paper describes how the adoption of Dope-Free connections is simplifying and improving the operational performance of Casing and Tubing operations and a methodology to analyze the efficiency of running operations.
Dope-Free connections are tubular connections with a multifunctional dry coating applied to their threads and seal areas in a controlled industrial environment that eliminates the need for storage and running thread compounds during the tubulars' full life. The impact of Dope-Free connection in an operation can be easily quantified by using readily available data. This is performed by analyzing the connection make-up charts (torque vs turns) of Dope-Free and standard connections from running operations.
Most connection problems and failed installations occur at the well site, driven by inexperience personnel, improper execution, and/or wrong interpretation of the make-ups caused by variability on the behavior of thread dopes under different environments. Removing the thread compound from the connection reduces the risk by having a lower possibility of miscommunications, connection damage, improper procedures, and applying the wrong dope. Although initially driven by environmental issues, the elimination of storage and running compounds from Casing and Tubing strings brings an array of benefits, from improved operational performance and HSE to well productivity. Operators experiences, after a short learning curve, showed great reductions in installation time, reduction on connections re-make ups and rejects along with improvement on workers' Health & Safety conditions by eliminating unsafe tasks and creating cleaner work areas, and minimization of the environmental impact.
The rig time saved due to less remake-ups and rejects of a Dope-Free connections running compared to standard connections can be easily converted to economic savings. This is especially important for offshore operations where high daily rate cost rigs are used.
Integrated Gas Blending and Optimisation
Authors: Muhamad Sori Zohairen Bin , Hashim Sharipuddin Bin , Chun Leo Andy Kee , Orenstein Horia 
Published: March 2016

Abstract
BIG DATA and GAS NETWORK MANAGEMENT: two extremely different terminologies used in the past in extremely different contexts. This paper details the effort and success by Malaysia Petroleum Management (MPM), PETRONAS. This initiative was supported by SAS Institute and Protechnology/Netgas. It is to merge the 2 worlds and handle the current challenges met in the management of complex upstream gas pipeline networks with an innovative and effective solution based on the principles of big data analytics.
The starting point was for us to gather the requirement to respond quickly and accurately to demand volatility and changing network operation conditions, while complying with the tripartite commercial agreements between PETRONAS, our natural gas customers and our Petroleum Arrangement Contractors (PACs). A software solution was developed to put the gas flow process, with its fluid- and thermodynamic rules, in the center of the operational process of gas gathering and blending, as well as the management of related commercial transactions and pipeline network operation management. The solution optimizes the volumetric transactions and ensures the delivery quality of the natural gas, supplied from different platforms at different qualities, while ensuring operational controllability with precise operator guidelines. It ensures so the highest operational regularity and planning flexibility. The modular software solution brings a couple of important innovations like dynamic calculus-numerical modeling of a full pipeline network, reverse simulation which optimizes automatically the supply and controls to meet the demand, integration of the commercial volumetric logic with the operational fluid- and thermodynamic, workflow automation and data and information integration. Supporting existing business processes, like planning, scheduling and operational monitoring, the fast staged implementation approach and the ease of use round up the benefits of this innovative solution with low entry barrier.
Low Pressure Enhanced Liquid Recovery System LP-ERS
Authors: Jothy A. , Thiruthonder H. 
Published: March 2016

Abstract
The LP-ERS process is suitable for implementation on marginal and stranded crude and associated gas producing fields where associated gas is used as fuel and/or flared. Whilst flaring of associated gas is not recommended, in many instances this is unavoidable due to various techno-commercial considerations. Crude and associated gas production facilities typically receive production fluids from wells at relatively low pressures, ranging from 5 barg to 20 barg. At these pressures, there would be significant quantities of C4+ components that can be extracted as condensates and stabilized with the crude. However, conventional enhanced recovery systems currently available are bulky and costly, resulting in these enhanced recovery systems not being implemented for marginal and stranded developments.
The LP-ERS is a proprietary process, particularly developed to address the abovementioned issues, to extract condensates (C4+ components) from low pressure associated gas in a cost effective manner, without the need for bulky compression, refrigeration and dehydration facilities that are typically required for conventional enhanced recovery systems. Apart from increasing revenue due to increased volume of stabilized crude production which is generally in the range of 5% to 25% (depending on wellstream fluid GOR, etc.), the implementation of the system will also significantly reduce greenhouse gas emissions (by approximately 20%) and improve the quality of the bulk stabilized crude oil produced.
Free Oscillation Analysis of Floating Bridge Panel at Different Water Depths
Authors: Madhuri S. , Muni Reddy M. G. , Manchala Savithri 
Published: March 2016

Abstract
There are different kinds of bridges to cross from obstructions. Bridges which are constructed to cross water body needs special attention in the analysis and design. Usually these bridges are being constructed with large amount of construction material and leading to increase in construction cost. As the structures are fixed and the deck levels are fixed, sometimes alternative proposals like rising of deck level are being proposed and implemented for navigational purposes across the bridges. The dynamic characteristics of the floating bridge play a major role in the response of the bridge under water flow or any wave action. In order to assess the dynamic characteristic of a floating bridge numerical studies are performed at different water depths by developing a MATLAB code using Newmark's Beta method. The concept of a floating bridge takes the advantage of buoyancy of water to support the dead and live loads thus reduce the construction material when compared with the conventional fixed bridges. The proposed floating bridge consist different number of panels. One or two panels can be detached from the floating bridge to allow the navigation of boats or ships across the bridge. Experimental and numerical free oscillation studies are performed at a water depth of 32.7m and results are compared well. Numerical studies are performed for 50 and 80m of water depth and results are presented.
Evaluation of Different Hydrate Prediction Software and Impact of Different MEG Products on Gas Hydrate Formation and Inhibition
Authors: AlHarooni K. M. , Barifcani A. , Pack D. , Iglauer S. 
Published: March 2016

Abstract
New hydrate profile correlations for methane gas hydrates were obtained computationally (using three different hydrate prediction software packages) and experimentally (with three different MEG products from different suppliers). Methane gas with pure distilled water was the benchmark case used for the software comparison at pressures of 50 to 300 bar. In order to compare the hydrate inhibition performance of the MEG products, aqueous 10 wt% MEG solutions were tested using the isobaric method at a pressure range of 50 to 200 bar.
Furthermore, the kinetics of MEG hydrate inhibition were studied experimentally for methane gas using a stirred cryogenic sapphire cell. Hydrate formation start, hydrate dissociation initiation and hydrate dissociation end points were identified and analysed. The results were correlated with the hydrate formation start points predicted by three well known selected hydrate prediction software packages (which all use the Peng-Robinson equation of state). Moreover, the hydrate inhibition performance of the three MEG products was evaluated to determine the superior MEG product that provides the best hydrate inhibition performance.
Our analysis shows that the hydrate formation points predicted computationally are not identical to the hydrate formation start points measured in this work. Software "A" and software "B" predicted results matching with the average curve of the experimental hydrate formation start and hydrate dissociation start points, and with a deviation value of 0.06 °C for software "A" and a deviation value of 0.03 °C for software "B". However, software "C" predicted results almost identical with the experimental dissociation start points, and with an average deviation value of 0.54 °C.
The methane gas hydrate profiles for the three different MEG products (X-MEG, Y-MEG and Z-MEG) indicated that X-MEG was the most efficient inhibitor as it shifted the hydrate curve most to the left; X-MEG shifted the hydrate formation curve by an average temperature of 2.07 °C when compared to the benchmark curve (100% water); while Z-MEG shifted the curve by an average temperature of 1.81 °C and Y-MEG shifted the curve by an average temperature of 1.71 °C.
We conclude that not all software packages predict the same results although they are all based on the same equation of state. Furthermore not all MEG products supplied have the same hydrate inhibition efficiency. Importantly, choosing the best MEG supplier will reduce the OPEX by reducing the amount of MEG used, and it will accommodate more relaxed operating conditions of lower temperatures and higher pressures.
Numerical Modelling of Seismically Induced Settlement for Ichthys Riser Support Structure
Authors: Erbrich C. , Wallbridge P. , Yamamoto N. 
Published: March 2016

Abstract
The Ichthys Riser Support Structure (RSS) is a very large subsea structure for supporting up to 25 flexible risers and umbilicals as they transition from the seabed to a semi-submersible Central Processing Facility. The Ichthys field is in a region affected by both local shallow crustal earthquakes and major subduction earthquakes emanating from the Australian/Eurasian plate boundary. Large beds of uncemented carbonate silts and sands are present at Ichthys, which are highly prone to excess pore pressure accumulation and liquefaction under cyclic loads. Any structure placed on the seabed will suffer from both co-seismic and post seismic settlement after an energetic earthquake event.
This paper presents dynamic non-linear numerical analyses (2D and 3D FEA) of the coupled soil and structure that were performed in order to estimate the seismically induced settlement and the potential extent of soil liquefaction beneath the RSS, which is founded on a large skirted raft foundation. Extensive site specific laboratory test data, defining the material behaviour during and after cycling, was collected to provide the necessary input to this analysis.
Significant areas of liquefaction (in the form of cyclic mobility, not flow liquefaction) were found under DLE conditions and hence the combined co-seismic and post-seismic foundation settlements were predicted to be substantial although tilts were modest due to low eccentricity of the centre of gravity. The RSS was demonstrated to be tolerant to such large settlements and hence the results were shown to be acceptable in this case.