bluuebunny/crossref_metadata_2025_split huggingface dataset:
Investigation on Erosion Due to Fine Particles in Multiphase Flow
Authors: Ngo Tran Nguyet , Peng Deng-Jr , Pao William , Ya Hamdan , Rohaizad M. Norpiah 
Published: March 2018

Pipeline production system often experiences complex multiphase flow and entrained fine-particles. The erosion due to solid fine particles presents one of the greatest threats to oil and gas flow assurance and consequently impacting material selection and wall thickness design. Limited literature is available on erosional effect caused by submicron particles such as fine sand, abrasive solid materials or gas bubbles. Previous studies on particle erosion are limited to particle size greater than 100 microns in single phase fluid flow. This is based on the assumption that potential for erosion by particle size smaller than 100 microns (specifically lesser than 62.5 microns) is insignificant. Additionally, very few studies have addressed the combined effect of erosion caused by micro-sized particles and multiphase flow.
Most predictive erosion models are limited to single phase flow for model simplification purposes. Hence, the effects of multiphase flow and its interaction with sand particles, specifically fine solids, are neglected. Therefore an in-depth understanding of multiphase flow regimes and its interaction with micro-sized particles is an important enabler for more accurate erosion prediction. For more accurate flow modeling and erosion characterization, computer fluid dynamics (CFD) tool is required. In this study, Multiphase CFD (MCFD) is implemented for predicting micro-fine erosion, considering two phase flow pattern features. Concurrently, trajectories of fine particles' bombardment on the pipe inner wall surface are captured using Lagrangian Particle Tracking Model. Analyses are carried out for water and gas flow at isothermal conditions, covering various particle size lesser than 62.5 microns in order to determine material removal rate. The results will be benchmarked against Tulsa multiphase erosion model prediction.
Based on the results, it is concluded that the erosional effect caused by micro-sized particles is strongly dependent on the flow patterns in the pipe, determined by superficial velocities of each phase. Additionally, erosional impact or material removal rate is predicted, which though small, is expected to significantly impact material design. The presence of these micro-sized particles acts as an enabler, which produces homogeneous "pits" on the surface of metal, significantly increasing the contact surface area for chemical and mechanical interactions to take place. The results from the proposed modeling using MCFD are expected to benefit erosion impact assessment in multiphase hydrocarbon production and piping systems.
A Review of Recent Progress in Developing Water Quality Measurement Instruments for Subsea Separation and Produced Water Re-Injection or Discharge Applications
Authors: Yang Ming , Latif Zak 
Published: March 2018

Abstract
Subsea separation and produced water re-injection (PWRI) or discharge has long been considered as an enabling technology for developing deepwater / ultra deepwater and marginal fields. It is an integral part of the subsea processing strategy which brings many economical, operational and environmental benefits for the offshore Oil & Gas industry. However, one of the key technology gaps remaining is in relation to water quality measurement for subsea separated produced water. This review is based on JIPs that NEL has conducted and its recent involvement in a RPSEA project. The review also includes progress made by operators and vendors.
Existing practice for subsea water quality measurement involves in sending an ROV (Remotely Operated Vehicle) to take a produced water sample and then bring it to surface for analysis. This practice is extremely expensive, time consuming and not good for operations. The technology gap has in many ways prevented the widespread of using subsea separation and produced water re-injection systems.
Good progress has been made in developing a subsea water quality measurement device in recent years. This has been achieved through a combination of efforts by operators, government bodies, vendors and independent organizations. Technologies that have the best potential for subsea applications include: Light scattering;Microscopy imaging;Laser Induced Fluorescence;Ultrasonic acoustic.
Most of the above-mentioned technologies are currently surface proven. They are of Technology Readiness Level (TRL) of 3 in relation to subsea applications, which means that they are prototype developed, function and performance assessed. Some of the key progresses to date are resulted from the use of LED as a light source, better fouling mitigation approaches, purposefully conducted lab and surface field trials. Further progresses are anticipated in which some of the mentioned technologies will be developed to TRL 4 (environmental tested) and TRL 5 (system integrated).
There are currently very few references in the literature on the subject. This paper will add valuable information to the public domain regarding the status of the development of subsea produced water quality measurement sensors.
The Mid Atlantic Current Hindcast MACH
Authors: Stephens R. V. , O'Neill C. K. , Siddorn J. R. , Cox A. T. , Harris E. , Orelup E. 
Published: March 2018

Abstract
The objective was the generation of a long-term layered ocean current dataset for the central and southern Atlantic Ocean, of suitable quality to support deep water offshore engineering design, marine operational planning and oil spill simulation. A model scheme was formulated to provide a reference fine resolution offshore grid covering the Atlantic Ocean from 30 degrees north to the Antarctic land mass. Very fine resolution grids were nested to model the continental shelf and slope regions of principal interest for oil and gas exploration and production. Various schemes were evaluated for representation of the riverine discharge, which is of major importance in some parts of west Africa. Additionally, optimal data assimilation scheme formulation was considered in order to best represent ocean surface topography, registration of major dynamic features such as fronts and eddies, and also correct characterisation of ocean density structure. Particular attention has been given to the equatorial region where energetic Kelvin wave propagation is generated by wind forcing; such waves contribute significantly to the most severe ocean current speeds, but can be spuriously misrepresented by inappropriate assimilation of erroneous observational data. The computational runtime required to undertake a long-term ocean reanalysis was large, even when using a major supercomputing facility. Therefore, it was extremely important to ensure that the model configuration was optimised in a structured pilot evaluation in advance of the full production run in order to achieve ‘fitness for purpose’ for the intended applications of the resultant dataset. This paper discusses the detailed process of structured model optimisation, where various permutations of setup had been validated against available in-situ measurements. The final model has now been completed for a 20year run and has been used in a number of regional metocean studies for Oil and Gas clients. The inclusion of location specific processes offers significant advantages over previously existing models.
Underbalanced Nitrified Foam Drilling Enabled Extensive Reservoir Characterization and Production from a Highly Depleted Formation in Dhodak Field in Pakistan: A Case History
Authors: Khalid Ali , Ashraf Qasim , Luqman Khurram , Channa Munsif , Hussain Muhammad 
Published: March 2018

Abstract
The Dhodak field is located in the eastern Sulaiman Range in Pakistan. The first well drilled there in 1975 produced gas and condensate from the Pab sandstone intervals created in the Cretaceous Age. Drilling any well in the field results in severe circulation losses because of the younger carbonate horizons of the Eocene Age, which includes the Habib Rahi and Rubbly Limestone. Operators cure these losses by spotting lost-circulation material (LCM) pills and deploying numerous cement plugs. In one particular well in the Dhodak field, an operator encountered an unexpected well-control scenario when drilling through the Rubbly Limestone, which further confirmed the potential for hydrocarbons in the horizon.
To explore the potential of the Rubbly Limestone, the operator drilled a dedicated well named Rubbly-1 using a conventional mud system and, as expected, encountered total loss of circulation. Drilling continued to the target depth, with heavy LCM pills and four cement plugs to cure losses. A prospective production interval was identified, and subsequent drill stem testing (DST) was performed. The well did not flow in the DST even after numerous attempts to kick it off. An evaluation determined that bridging materials had extensively invaded the formation when attempting to cure losses. The invading materials had clogged the pores of the reservoir formation, which resulted in no production and subsequent abandonment of the well.
Underbalanced drilling provided a feasible solution that allowed the well to flow while drilling and eliminated overbalanced pressures and invasion damage. The reservoir pressure measured just 5 lb/gal (599 kg/m3) in equivalent mud weight. The low pressure of the formation meant it could only be drilled with a foam system.
A suitable foam system provided a low equivalent circulating density that enabled drilling the Rubbly Limestone formation. By applying an underbalanced nitrified foam system, the operator drilled the horizontal to the target depth (TD) without any issues. The well started flowing while drilling, and the operator evaluated the reservoir potential by performing surface testing and openhole wireline logging, which resulted in logs with excellent resolution. This paper details the design criteria, equipment selection, and wellsite execution program used for drilling and evaluating the Rubbly Limestone formation.
Improving the Competency Assessment and Verification Process for Wells Personnel Involved in Safety and Environmentally Critical Operations will Improve HSE Performance and Reduce Major Accident Incidents.
Authors: Kinkead Brian 
Published: March 2018

Abstract
This paper reviews present methods and shares best practice in conducting competency assessments, including their verification, for wells personnel involved in safety and environmentally critical operations with a view to improving HSE Performance and Reducing Major Accident Incidents.
The wells personnel included are those identified Oil & Gas UK (OGUK) as the minimum positions involved in safety and environmentally critical operations. This paper includes a review of the OGUK industry Guidelines on competency for wells personnel – Issue 2 (OGUK, 2017), a review of the assessment and verification procedures associated with the UK guidelines "Industry Guidelines for the Management of Competence and Training in Emergency Response for Offshore Installations – Issue 3, (OGUK, 2010) and other industry findings such as the Office of Railways Safety and Standards Board (ORR).
There is a wide variance on which direct and indirect assessment methods are used for different onshore and offshore positions. The paper draws conclusions on which methods work best for given positions, how assessors are trained to carry out assessments, the validity of using independent assessors and the benefits of standardizing certain elements of assessment.
A conclusion on the role that professional institutions, including the SPE, may play in the overall assessment of competence is examined. The wide variance of verification methods is reported on and recommendations made on their suitability. The potential for standardization of certain elements of the assessment and verification process will lead to savings, improved utilization of personnel and quality of assessments. Ensuring that assessments are of a common and consistent high standard will improve overall Health, Safety and Environmental performance and help reduce major accidents.
First Pressurized Mud Cap Drilling with Top Kill Application in Malaysia Development Wells
Authors: Idris M Faisal Rizal , Fabian Oka , Hua Lai Yen , Arathoon Mark , Musa M Zarir , Musa Syahirah , Johari M Raimi 
Published: March 2018

Abstract
In 2016 PETRONAS embarked on the challenge of drilling and completing high temperature, highly deviated fractured carbonate development wells using Pressurized Mud Cap Drilling (PMCD) techniques. With equivalent formation pressure gradients of 13ppg, H2S levels of 140ppm and formations with potential for massive losses, but also very high gas productivity, severe challenges were presented to the drilling engineering and operations teams and to the logistical infrastructure; these challenges were successfully overcome, ensuring that the wells were delivered safely using the planned Tender Assisted Drilling Rig.
Maintaining well control integrity throughout all drilling and completion operations is always crucial to ensuring safe well delivery. In wells with total losses, drilled through highly productive carbonate formations, there is a high risk that any loss of the primary drilling fluid barrier may result in the well flipping out to gas very rapidly. This risk is highest during trips out of the hole, when the Rotating Control Device (RCD) pressure seal must be removed to retrieve the drilling BHA and run the lower completion. For wells with total losses, options to control the well during trips have traditionally involved a combination of methods including setting gunk plugs, setting composite bridge plugs, or using a preinstalled Downhole Isolation Valve.
The purpose of this paper is to present a fourth option, the top-kill method using a dual-density fluid system. During the 2015-2016 PETRONAS development drilling campaign, following thorough risk assessments and detailed planning and logistical evaluation, this method was proven to be a reliable and safe means of controlling the well during trips.
A total of five (5) wells were drilled from the development platform, using a surface BOP stack and an RCD. Top kill operations were engineered by pumping two types of fluid into the annulus at surface; a slightly underbalanced Light Annular Mud and a heavier density Kill Mud. By combining these fluids, the well was put into an engineered overbalanced state, with the loss rate controlled via a pre-determined pumping rate. Once the RCD seal element was re-installed, the well reverted back to pumping Light Annular Mud into the annulus as per normal PMCD procedures.
This paper highlights the meticulous planning, execution, training and continuous learning that was evident in these challenging operations. This paper also discusses critical HSE concerns and makes recommendations for future PMCD projects.
Enabling SIMOPS from Jack-Ups
Authors: Zijderveld G. H. T. , Bonte S. J. , Tiebout J. J. 
Published: March 2018

Abstract
In today's environment drilling, well workover and well intervention operations call for increased efficiency and safety. Concurrent operations are a method to increase efficiency. However safety should not be compromised. An innovative device has been developed to enable SIMOPS (Simultaneous Operations) from a jack-up.
An analysis has been made to identify which operations, when executed from a jack-up, would benefit from the possibility to be done concurrently. Typically most well operations are done through the rotary table. Those operations are either using drillpipe, wireline or coiled tubing. The operations are thus often sequential and allow for working at one well at the time.
On production platforms with multiple wells it would be of interest to work on more than one well at the time. For example working on one well with drillpipe while working on another well with wireline or coiled tubing. Also the setting and retrieval of temporary plugs can be done faster while not compromising safety.
While the primary load path on a jack-up is through the rotary table some operations do not really require the high lifting and lowering capacity which is offered by the topdrive assembly in the derrick. Especially for wireline and coiled tubing operations the lifting and lowering capacity can be much lower.
So an add-on device with reduced load capacity which enables non-drillpipe operations can be advantageous. Especially when it can be working free of obstructions under the cantilever of the jack-up.
The new add-on device will increase rig efficiency during development drilling, well workover/intervention and plug & abandonment operations. It for instance enables wireline guidance into the well through its moveable arm with the hoisting point below the cantilever. This while other operations on an adjacent well are executed simultaneously through the rotary table.
Nano-Sized Particle as Foam Stabiliser Designed for Application at High Temperature and Light Crude Oil Condition for Enhanced Oil Recovery - A Fluid-Fluid Case Study
Authors: Razali Norzafirah , Hsia Ivy Chai Ching , Zainal Suzalina , Manap Arif Azhan A 
Published: March 2018

Abstract
Foam Assisted Water-Alternating-Gas (FAWAG) flooding is one of the enhanced oil recovery (EOR) technique that had been explored and studied worldwide. The ability of foam to lower the gravity override and create a macroscopic sweeping of oil in the reservoir shows its potential to be a successful technique. However, the rapid degradation of foam at high temperature condition in the presence of light crude oil limits its application. Therefore, introduction of an additive to the surfactant is crucial to maintain foam stability. Nano-scale particle is a well-known material that has attracted a lot of attention due to its unique physiochemical properties. This high surface energy particle has shown to exhibit a catalytic behaviour in various application including EOR chemical flooding. In this study, the effect of four different types of nanoparticles, SiO2 (hydrophilic), SiO2 (hydrophobic), ZnO and TiO2 nanoparticles on foam stability under high temperature condition, and in the presence of light crude oil were investigated. Results from this study has shown that SiO2 nanoparticles of the hydrophilic type at concentration three times lower than the surfactant concentration have significantly improved the foam half-life by 2 times longer than the surfactant alone at temperature of 110°C, in the presence of light crude oil (45° API). No improvement of foam half-life was shown by ZnO nanoparticle used in the surfactant formulation. The presence of SiO2 (hydrophilic) nanoparticles have significantly reduced the detrimental effects of light crude oil and strengthen the foam by increasing the viscosity of surfactant from 4.38 cP to 10.01 cP in the presence of 0.15 wt% SiO2 (philic) nanoparticle. The significant increment in viscosity has maintained the wetness of foam, thus reducing the rate of liquid drainage at the temperature above boiling point of water. The SiO2 (hydrophilic) nanoparticle-surfactant formulation was observed to have produced uniform sized bubbles compared to surfactant formulation alone. This indicates that nanoparticles are able to restrict shrinkage or expansion of bubble by creating a steric layer at the lamella structure which consequently restores the foam stability. The foam stability tests, determined as foam-half-life, were performed using inert nitrogen gas as the gas phase to eliminate other factors that may affect foam stability.
Floating Unit Mooring Integrity Management - Experience in the Malaysian Water
Authors: Rahman Hirzi Abd , Keresnan Hariharan , Hamid Ir. Saifulbahari Abdul 
Published: March 2018

Abstract
The present paper documents how best industry practice for Mooring Integrity Management (MIM) are implemented regionally in the Malaysian waters. Observations from in-situ inspection of mooring systems situated in Malaysian waters have been collated for a number of Floating Units that have different types of mooring systems: spread moorings, external turret moorings with chain table above and below the mean water line. One mooring system was recovered and brought back at the yard for detailed inspection. The observed degradation rates due to wear and corrosion has been measured. Operational feedback gathered during the offshore campaigns is also given. This information is shared with all the stakeholders involved in the MIM process to further improve their own internal procedures, in-house knowledge, tools, or decision-making criteria for best practice to continue being applied in the region.
The Feasibility Study of OTEC Integration on a Semi-Submersible O&G Production Platform
Authors: Yen K. , Jing X. 
Published: March 2018

Abstract
Ocean Thermal Energy Conversion (OTEC) technology uses the water temperature gradient between the cold deep ocean and the warm ocean surface to generate clean renewable power. This system requires one or several cold water pipes (CWPs) of large diameters to transport large amounts of deep-sea cold water to the floating platform topside. Until now, there is no stand-alone floating OTEC system in operation offshore, partly due to the associated high capital expenditure (CAPEX). In this study, a cost-effective approach for small-scale OTEC technology application is introduced by integrating one compact OTEC module directly onto a semi-submersible oil and gas (O&G) production platform. In addition to the mooring lines and risers, the CWPs would be attached to the columns of the semi-submersible platform in a way similar to that of vertically hanging risers. This study assesses whether installing four CWPs associated with a hypothetical 1 MWe OTEC module on a semi-submersible production platform would have any major effect on the hull global motions and the dynamic performance of the risers and moorings. The study investigates the feasibility of a small OTEC system installation on a semi-submersible platform and provides useful reference and guidance for OTEC technology applications on O&G facilities in general.
Global motions of a semi-submersible hull due to the installation of the OTEC module and CWPs are studied using nonlinear fully coupled time-domain analysis. The parameters of the CWPs which are investigated include length variation. The sensitivity of the hull motions is checked considering several design environmental conditions. The hull global motion and riser dynamic performance are analyzed using engineering analysis programs. The global motions from coupled analysis are applied to detailed Finite Element Analysis (FEA) models of the CWPs for strength checking. For large diameter CWPs, a slight discrepancy in the modeling and wave or current load calculation in the global coupled model and the CWP detailed FEA modeling could result in a significant error in the computation results. For this paper, the simultaneous approach is adopted by TechnipFMC in-house programs, i.e. coupling RodDyn with MLTSIM for global coupled motion analysis and stand-alone RodDyn for CWP FEA analysis. Identical CWP modeling is used in both coupled analysis and detailed FEA simulation.
From coupled analysis of the proposed semi-submersible system with CWPs, the effects of the CWPs are found to be significant yet not detrimental to the floating platform system performance as they could be mitigated in the design. Thus, installing a small pilot scale OTEC module on a semi-submersible production platform to generate around 1 MWe of electrical power is shown to be feasible.