bluuebunny/crossref_metadata_2025_split huggingface dataset:
Commingle Zubair Shale Sand Sequences by Using Deformable Sealing Polymer in Customized Drilling Fluid, Case Histories from Kuwait
Authors: Al-Ajmi Abdullah , Al-Rushoud Abdulaziz , Gohain Ashis , Khatib Faiz I , Al-Naqa Faisal , Al-Mutawa Faisal , Al-Gharib Majed , Birthariya Sudhir , Mago Ankit , Al-Mekhlef Alanoud , Al-Tarkeet Bader , AlAli Yaqoub , Rossi Arnaldo , D'Angelo Dario , Spagnoli Nazareno , Samaan Fady , Rane Praful , Scolari Alberto 
Published: March 2018

Abstract
Shale stability and differential sticking are the main challenges while drilling through shale and sand sequences. Conventional mud systems cannot always provide the required wellbore stability and sustained high overbalance, which has led to an increase in use of ‘customized fluids’.
Offset wells were reviewed to identify the issues while drilling this challenging trajectory through troublesome stressed Zubair shale and sand sequences. This review revealed serious well-bore instability, pack offs, differential stuck pipe leading to the loss of downhole tools and sidetrack operations.
Traditionally, oil-based mud (OBM) have been used while drilling these formations with high NPT hours. Due to necessity of comingling two sections in a single section, it was necessary to identify a fluid's solution, which can provide good borehole stability.
A customized drilling fluid system was designed by using deformable sealing polymer (DSP, deformable size) in conjunction with Synthetic Resilient Graphite and Sized Calcium Carbonate (CaCO3) in conventional OBM. These Nano particles effectively plug the pore throats and minimized the fluid invasion, which was confirmed by particle / permeability plugging tests under down hole conditions to overcome below challenges. Improve hole stability through stressed shale formationsMinimize risk of differential stuck pipe across low pore pressure formationsMitigate induced losses by utilizing unique wellbore-strengthening techniqueEnhance hole-cleaning efficiency at critical angle
Drilling, logging, running and cementing liner was successfully completed in the commingle section without any incident. There was no NPT related to well-bore instability or differential sticking tendency reported. Very low torque and drag was observed in addition to enhanced well-bore cleaning in the high angle section.
This paper will present the success of the deformable sealing polymer in OBM utilized to comingle Upper Zubair shale and Ratawi shale with case histories for reference.
In-service Riser Inspection System IRIS
Authors: Nicolas Yann 
Published: March 2018

Abstract
Flexible risers are fundamental enabling components of nearly all floating production systems and form a key link in the hydrocarbon delivery chain to and from the platform. The integrity of these risers can drive the uptime availability of the entire production system or at least some elements of it. While the historical reliability of flexible risers has been relatively high, operators remain concerned about a lack of integrity condition information available to make key decisions relating to changes in operating conditions, replacement, life extension and general maintenance. The resulting increased confidence in the performance of flexible risers potentially could open the market to greater acceptance of flexible pipes and additional floating systems developments.
A new approach to in-service inspection of flexible pipes is presented in this paper. TechnipFMC develops a versatile subsea inspection tool (IRIS) that can deploy and operate in parallel several Non-Destructive Testing Technologies. This new generation of an in-service subsea inspection system for risers focuses on detection of defects on multi layers products (corrosion, cracks and breaks) and flooding detection. IRIS is remotely controlled and operated in real-time via an umbilical from the control room on a support vessel. Given its architecture, this "Underwater Non-Destructive Testing laboratory" also allows inspecting risers without stopping the production under water, in the splash zone as well as in its aerial part when relevant. Thanks to its in-depth knowledge of flexible pipe and specific Non-Destructive Testing modeling tools, TechnipFMC will propose a dedicated inspection strategy for each flexible pipe.
Hybrid Riser Towers - Not Just for Deepwater
Authors: Lim Frank , Natarajan Shreenaath 
Published: March 2018

Abstract
Most people know the Hybrid Riser Tower solution, combining the use of steel pipes in a freestanding bundle and multiple flexible jumpers for connection to a floating host vessel, from the 3 towers installed in 2001 offshore Angola in 1,350m water depth to the Girassol FPSO.
Little known is the fact that the first bundled riser tower, in a slightly different arrangement preceding Girassol, was actually installed by Placid in Green Canyon (1988), and the same riser tower was later re-deployed by Ensearch in Garden Banks (1994, now decommissioned), both in the Gulf of Mexico in less than 650m water depth to a semi-submersible production platform.
This paper describes the adaptation of the bundled hybrid riser tower concept for subsea connection to a FPSO in Indonesia in only 90m water depth. The ‘mini’ riser tower, comprising 6 risers in the bundle and installed in 2013, made full use locally available materials, fabrication labours, skills and facilities, and installation capabilities in the region. This project, and its successful implementation, paves the way for more SE Asian operators to maximise local contents, optimise costs and exercise better project control for their upcoming developments.
This hybrid riser tower solution can lend itself readily for HPHT field developments, or aggressive production fluids, when conventional riser solutions such as bonded or unbonded flexible pipes, and corrosion resistance alloy (CRA) clad steel catenary risers cannot handle the fluid properties or the shallow water depths, respectively. Work is underway to use high quality thermoplastic composite pipe (TCP) as the jumpers in a hybrid tower to overcome the chemical issues.
Integrated Field Performance Study for Subsea Production Control System
Authors: Hammond Steven , Osman Hazreen , Ismail Izyani 
Published: March 2018

Abstract
The subject of this study is a Subsea Production System comprising of two (2) subsea gas production wells. The gas, condensate and water from the wells are sent to a processing platform via 4.71 km 24" subsea pipeline. The two wells are independently connected to a production manifold with 12" branch lines and 2 off 12" headers, each with its own dedicated HIPPS module (as shown in Figure 1). The manifold-mounted integrated HIPPS units are SIL 3 rated to protect the pipeline system, which also includes a Subsea Automated Pig Launcher (SAPL), from an overpressure condition as the pipeline has lower design pressure than the Subsea System. The two wells are then commingled in the PLET via 2 off 12" headers.
The operation of the subsea facilities is monitored, controlled and operated from a Central Processing Platform (CPP), through electro-hydraulic-chemical umbilical running to the two subsea wells. Utilities for subsea facilities (e.g. electrical power, chemical injection and hydraulic fluid) are also supplied from the CPP.
A Full Field Review (FFR) study has been conducted to identify and implement (as far as possible) opportunities for increasing production and improving recovery factor, maximizing asset value of the subsea field. At time of writing a detailed facility evaluation is being performed as part of the Full Facility Review. The result and findings from the FFR form the basis for future development, identifying potential bottlenecks, key risk or opportunity areas on existing facilities.
Best Practicable Environmental Options Assessment for Drilled Cuttings and Fluids Waste Management Strategy
Authors: Yudistira B. 
Published: March 2018

Abstract
Tangguh Integrated Drilling Project (TIDP) is being rolled out by BP Indonesia as part of long term development plan for Tangguh project in Bintuni Bay, Papua Barat Province. The offshore drilling campaign consists of several development, exploration, and appraisal wells throughout the bay. The complex scope of work for TIDP and regulatory requirement require a systematic holistic approach to come up with appropriate drilling fluids and cuttings waste management strategy.
A multidisciplinary team consists of: Wells Engineering, Operations, Health Safety and Environment, New Wells Delivery, Regulatory Compliance & Environment, Communications & External Affair, Permits, and Central fluids were established to discuss the strategy. Best Practicable Environmental Option (BPEO) tool was decided to be used. The assessment model incorporates weightings for criteria which enables more important criteria to be emphasized and also enables sensitivity checking. BPEO process flow are as follows: define objectives, decision criteria and scoring matrices, weight the decision criteria, identify all possible options, pre-screening, full assessment, review and rank options, and finally identify the BPEO.
The study concludes that for cost effectiveness, practical application, efficiency, HS&E risk mitigation, and reduced (if not elimination of) long term liability, the waste processing and disposal should take place at the rig site. The study further concludes that there is no single best option for all drilling locations due to different constraints. Therefore, the recommendation is to have the combined option of Drilling Cuttings Re-Injection (DCRI) and overboard discharge that can be utilized across all locations in Tangguh. With this study, the team is not only eliminating the environmental and safety risk inherent in offshore drilling, handling and transportation of large amount of drilling cuttings and fluids waste, but it also save costs on constructing several dedicated DCRI wells and reduced 200 drilling days from the jack up rig scope. Another impact is that it reduces the carbon footprint and greenhouse gases coming from the drilling and its supporting activities such as vessel utilization.
The result from this BPEO can support management, engineers, and operations team in the decision-making process to determine the most suitable option among several scenarios or any other complex project. It could also provide a sound justification to the regulators to expedite the permitting process.
Pushing Operational Limits in Challenging Perforating Environments
Authors: Samuel Orient Balbir , Fabian Oka , Rosato Miguel , Khalid Zaidan , Johari Raimi , Jusoh Zulaikar , Idris Faisal Rizal , Hamid Azim , Rosli Faidzal , Salleh Harris 
Published: March 2018

Abstract
The W field located north of the coast of East Malaysia, Malaysia in approximately 100 meters of water. Five dry gas wells, W1 through W5 were drilled and cased between Q1 and Q4 2016. The well depths fell between 3700 meters and 3825 meters measured depth (MDDF), 2with bottom hole temperatures as high as 180 degrees centigrade and formation pressures of 6500 psi. In addition, the wells were expected to be sour with 140ppm H2S and 20% CO2.
Originally the wells were planned to be completed with slotted liners, however this was proving to be problematic as it limited well control options and a safer solution was needed. An alternative un-cemented liner was run and it required to be perforated. TCP (Tubing Conveyed Perforation) and CTCP (Coiled Tubing Conveyed Perforation) were the logical choices, however after some considerable discussion it was agreed that wireline conveyed guns employing friction reducing rollers and tractors had the potential to save considerable rig time while satisfying all safety concerns. Detailed planning and simulation for this complex operation was required, the operator and service provider formed a strong technical alliance to achieve the objectives.
All five (5) wells were successfully perforated with a total of 840 meters of perforations achieved in 40 runs, 11 of them tractor conveyed, the longest gun string was 29 meters long and the total operating time was 783 hours. The campaign was completed with and operational efficiency of 94% and all objectives were meet. This paper describes the operational objectives and how careful planning managed to overcome the challenges encountered in these hostile environment. The case study underlines the efficiency of wireline conveyance in environments previously dominated by Coiled tubing and Tubing conveyance and highlights a new and powerful tool now available to operators.
New Flexible Pipe Cost Effective Solution for Static Application
Authors: Vraniskoski Kristof , Phelut Renaud , Legeay Sebastien , Gros Patrick 
Published: March 2018

Abstract
Flexible pipe is a cost-effective and tailor made pipeline solution. Nevertheless, today's demanding market conditions call for new solutions with further increased cost effectiveness to satisfy demand for a reliable and very economical solution.
The paper will focus on a new qualified solution whereby the interlocked pressure shaped armour wire is replaced by single strip made of carbon steel wound on the pipe with 50% overlapping. A large percentage of the market is dominated by smaller diameter (&lt;12″) pipe for low pressure, static flowline/jumper applications in shallow water, such solution will typically cover such domain range. In this paper will be covered the profile description and associated qualification tests, as well as the cost effectiveness and economic viability.
Currently, flexible pipes are suitable for a wide range of technical specifications, including inner diameters (ID) from 2″ up to 21″ ID, design pressure up 20,000psi, temperature up to 150°C and water depths to 3,000m. Such pipes are made of an interlocked pressure armour wire (shaped wires), resulting in relatively high inertia pipe, with added weight leading to manufacturing challenges and associated cost.
This new pressure armour strip profile was developed and qualified with the following outcomes: Reliable qualification of a technology from 4″ to 12″ ID following API RP 17B process.Significant cost reduction compared to current design in similar cases when this new technology is applied.Simple and cost effective installation feasibility facilitated by weight optimisation and associated top tension reduction (horizontal over boarding of the flexible pipe over a gutter using a tensioner or use of low tension vertical pipelay systems).
The new pressure armour strip profile (profiling of the strip) was engineering detailed, a reliable qualification program was conducted on 6″ flexible pipe following API RP 17B process. Such qualification program implies pipe characterization against: crushing, bending, internal pressure, burst limit, and deviated tension. Finally, cost impact assessment was conducted.
Some additional benefits associated with this innovative design include the elimination of pressure armour unlocking phenomenon during service or installation and reduced gas diffusion into the annulus.
Evaluation of Uintaite and Asphaltic Additives in Synthetic Base Fluids
Authors: Montes Dario , Sotomayor Ghery , Pascarella Natalie 
Published: March 2018

Abstract
Uintaite is a well-known drilling fluid additive that has been used in the oil and gas industry since the 1950's. Known globally as Gilsonite, the oil and gas drilling industry has adopted it as the standard; however, in recent years products have entered the market misconstrued under the same name. Uintaite is a unique naturally occurring asphalt-like rock found exclusively in northeastern Utah, and has been proven effective as an additive in a wide range of applications. Geologically, Uintaite is part of the asphaltite family along with other natural bitumens such as grahamite and glance pitch.
A preceding study discussed Uintaite performance in synthetic based systems including its ability to comply with the United States Environmental Protection Agency (EPA) standards for discharge. This paper follows the natural progression from that study, comparing Uintaite's performance in synthetic base drilling fluids against other asphaltites and asphaltic products, commonly referred to as ‘black powders'. A comprehensive evaluation was performed to understand the effectiveness of each filtration control additive on the base synthetic drilling fluids properties; while at the same time evaluating their potential impact in the original fluid formulation to comply with environmental regulation, providing rigorous technical data to assist the drilling industry in better understanding this key drilling fluids additive. This paper is intended to describe the differences between authentic Uintaite and other asphaltic products.
Corrosion Resistance Alloy Lined Pipe Seal Weld Assessment Using Finite Element Analysis and Full Scale Qualification Testing for High Pressure and High Temperature Pipeline Application
Authors: Putra I. W. Eka , Fuaddin N. A. H. , Mazli A. M. , Rosli F. , Badaruddin M. F. , Napiah M. N. M. Ali 
Published: March 2018

Abstract
Corrosion resistance alloy (CRA) lined pipe is one of the alternative materials for corrosion management in oil and gas application. It is generally more economical compared to CRA clad pipe. However, limited references are currently available regarding performance of CRA lined pipe for high pressure and high temperature (HPHT) pipeline. This paper presents PETRONAS qualification on the suitability of CRA lined pipe for one of its HPHT field. The work focused on the liner and seal weld failure mode due to wrinkling, bending and fatigue cracking during pipeline coating process, offshore installation and operation lifetime. The first stage assessment was conducted using finite element analysis (FEA). Various cases as an effect of pipeline global buckling were considered, including combined pressure, temperature, bending, axial load, cycled between shutdown to normal operating conditions, and effect of griping forces with or without the presence of imperfection. Full scale testing was then performed sequentially simulating full cycle of the pipeline loading, started by thermal loading (coating process), followed by full size four-point bending test (installation case), and lastly full cyclic bending up to maximum lateral buckling strain at design temperature (operation case). Liner gripping force test was then conducted following the full cyclic bending test. Fatigue performance of the seal weld under cyclic loading was also assessed through small-scale low cycle fatigue tests. Both FEA and full scale testing showed that liner pipe was not susceptible to wrinkling at the maximum global buckling loading, even without pressure. There is also indication of residual gripping force even the pipe has gone through full cycle of operation stage. The low cycles fatigue tests also shows high safety factor for the fatigue life. Hence, acceptability of the CRA under actual operating conditions will be higher since bending moments due to buckling occurs while the line is pressurized.
Improved Pre-Drill Pore Pressure Prediction for HPHT Exploration Well Using 3D Basin Modeling Approach, A Case Study Offshore Vietnam
Authors: Nguyen Son T. , Hoang Son K. , Khuc Giang H. 
Published: March 2018

Abstract
In this study, pore pressure prediction for a HPHT exploration well was conducted using both convention 1D modeling method and 3D basin modeling approach. Due to the considerable challenges encountered in three nearby fields (narrow mud weight windows, over pressure up to 17.0-17.8 ppg, and temperature as high as 185 °C at projected well TD), 3D basin modeling was considered as an alternative approach to help reduce the uncertainty due to lack of constraining data for conventional 1D modeling.
Both Eaton and Bowers methods were used to generate 1D models of the pore pressure profile from seismic interval velocity. Calibration of the models was based on offset wells of the three nearby fields. On the other hand, 3D basin modeling approach was used to model all three fields together. Detailed lithology was defined for each layer of the basin. By carefully calibrating the relationship of porosity-effective stress, porosity-permeability, and varying sealing capacities of the faults, a good match was obtained between the 3D basin pore pressure distribution and pressure data measurements from offset wells of all three nearby fields. After the calibration process, pore pressure profile of the HPHT exploration well was extracted along the proposed drilling well path.
Modeling a basin consists of reconstructing the deposition history of the entire sedimentary sequences from geological, geophysical, and geochemical data. It allows establishment of paleo water depths and heat flows in burial sediments to understand the hydrocarbon generation, migration, and accumulation processes during the geological history of a basin. The accurate definition for porosity-effective stress and porosity-permeability relationship of layers of source rock, reservoir, and seal will generate reliable pressure regimes in the basin. Extraction of 1D pore pressure profiles showed an excellent match with measured pressure in offset wells.
In addition to providing pore pressure prediction to optimize drilling plans, 3D basin modeling could deliver rock properties data for further wellbore stability studies in exploration areas. This is valuable for HPHT offshore drilling to help reduce the possibility and severity of drilling issues such as kicks, losses, and wellbore collapse.
Model simulations with COSMO-SPECS: impact of heterogeneous freezing modes and ice nucleating particle types on ice formation and precipitation in a deep convective cloud
Authors: Diehl Karoline , Grützun Verena 
Published: March 2018

Abstract. In deep convective clouds, heavy rain is often formed involving the ice
phase. Simulations were performed using the 3-D cloud resolving model
COSMO-SPECS with detailed spectral microphysics including parameterizations of
homogeneous and three heterogeneous freezing modes. The initial conditions
were selected to result in a deep convective cloud reaching 14 km of altitude
with strong updrafts up to 40 m s−1. At such altitudes with corresponding
temperatures below −40 ∘C the major fraction of liquid drops
freezes homogeneously. The goal of the present model simulations was to
investigate how additional heterogeneous freezing will affect ice formation
and precipitation although its contribution to total ice formation may be
rather low. In such a situation small perturbations that do not show
significant effects at first sight may trigger cloud microphysical responses.
Effects of the following small perturbations were studied: (1) additional ice formation via immersion, contact, and deposition modes in
comparison to solely homogeneous freezing, (2) contact and deposition
freezing in comparison to immersion freezing, and (3) small fractions of
biological ice nucleating particles (INPs) in comparison to higher fractions
of mineral dust INP. The results indicate that the modification of
precipitation proceeds via the formation of larger ice particles, which may be
supported by direct freezing of larger drops, the growth of pristine ice
particles by riming, and by nucleation of larger drops by collisions with
pristine ice particles. In comparison to the reference case with homogeneous
freezing only, such small perturbations due to additional heterogeneous
freezing rather affect the total precipitation amount. It is more likely that the
temporal development and the local distribution of precipitation are affected
by such perturbations. This results in a gradual increase in precipitation
at early cloud stages instead of a strong increase at later cloud
stages coupled with approximately 50 % more precipitation in the cloud
center. The modifications depend on the active freezing modes, the fractions
of active INP, and the composition of the internal mixtures in the drops.