bluuebunny/crossref_metadata_2025_split huggingface dataset:
Open Source Architectures Development for Subsea Factory
Authors: Radicioni A. , Fontolan M. 
Published: March 2016

Abstract
The future application of subsea processing technologies envisages subsea production systems with an increased level of functional complexity because of the integration of static and rotating processing equipment like pumps, separators, compressors, scrubbers, heat exchangers.
These systems call for high total system availability not only dependent on individual technologies and associated equipment reliability but also on a set of key drivers which shall govern the overall Subsea System configuration.
The field evolution during its life, due to the modification of the production parameters (like changing in production profiles, increased water production, etc…), together with the need for frequent inspection, maintenance and repair (especially for the rotating equipment) have to be considered when defining the key drivers to be evaluated in view of defining the best subsea factory configuration.
Elements such Interchangeability, Re-Configurability, Expandability, Installability, Inspectability and Retrievability have to be considered within the key drivers and functional requirements to be evaluated in the development of the subsea system architecture of these systems.
The standardization of modules and sub-modules and the standardization of interfaces among modules and sub-modules with Subsea Production Systems or other facilities shall be a key for the optimization of the subsea processing system vs. installation and Inspection, Maintenance and Repair (IMR) tasks.
Sonsub is active, since many years, in the development of proprietary subsea processing technologies. The proprietary solutions includes the Subsea Gas/Liquid Separation System (Multipipe Separator), Liquid/Liquid Separation System (SpoolSep), and The Sea Water Treatment and Re-Injection System (SPRINGS).
The Sonsub philosophy (Saipem brand name and industrial platform for the Subsea Factory) to optimize the subsea factories configuration is to develop "open sources architectures" through standardized Functional Building Blocks and standardization of the relevant interfaces.
The paper illustrates the "open source architectures" conceived by Sonsub for subsea factories and relevant modularization philosophy, mainly focused to its proprietary technologies. Moreover it also describes the proposed standardization principles to allow the integration of a system independent from any proprietary products or equipment and exclusive interfaces, called SUBSEA BUS.
Pull-In and Lay of Dynamic Umbilical Through Shallow J-Tube With Offset Touch Down Point Into Existing Platform
Authors: Eyssautier S. 
Published: March 2016

Abstract
Bayu-Undan is an existing gas field located North West of Darwin comprising of two main platforms, a satellite platform and an export pipeline to the Darwin LNG facility operated by ConocoPhillips. Phase 3 of the Bayu-Undan development included the lay of two flexible pipelines and one umbilical. The umbilical was installed by a leading seabed-to-surface EPIC contractor utilising a multirole construction and diving support vessel in September 2014, which presented a number of specific challenges: The umbilical system was unusual for the following reasons: ?Free-hanging catenary of umbilical to avoid in-place rigid spools (*)?Shallow water depth of J-tube bellmouth?Umbilical ancillaries that were designed before installation challenges were fully understood?The proximity of J-tube and lay corridor to the flare bridgeDetailed engineering on the following topics was completed to address the installation challenges: ?Installation Analysis of different methods for comparison, using a leading finite element based hydrodynamics simulation software?Design of bespoke stern-mounted horizontal lay spread?Rigging design for product limit conformanceThe following factors influenced a successful offshore campaign: ?Good weather?Smooth deck handling of umbilical?Good interface between vessel and platform team
This paper presents a case study of the engineering and installation activities and provides lessons learnt for the entire operation.
(*) the "dynamic" umbilical will be further refered as "free-hanging" umbilical as, being fixed both ends, it didn't experience any real dynamic behaviour.
Real Time 3D Modeling to Optimize Geosteering in Clastic Reservoir – Case Study
Authors: Bashir Faisal , Al-Hawi Maan , Bhuana Indra , Abbas Mazin , Ghamdi Yasser 
Published: March 2016

Abstract
This case study presents the impact of dynamically updating 3D structural and petrophysical geological models to optimize real-time geosteering through stringer sands with high effective porosities in clastic reservoirs. The depositional environment of siliciclastic reservoirs imposes reservoir development challenges due to heterogeneity within the play system and within each sediment. Historically, stochastic modeling techniques have been used to predict the extent of lithofacies between wells where no hard data exists. Combined with a proper understanding of the depositional environment, stochastic and deterministic modeling techniques (selection of which depends on the availability of well control data) can closely simulate the actual distribution of petrophysical properties and their variance within reservoirs.
Reservoir modeling has been used for reservoir studies and production simulation, historically with cell resolutions as coarse as 100's of meters/feet. Such models used to require hours to update. Today, advancements in modeling software and hardware allow higher resolution models to be updated in minutes. These advancements have triggered new opportunities for modeling, allowing model-centric approaches to be effectively integrated into time-sensitive workflows. Geosteering is one of the evolving reservoir development and drilling frontiers where accurate real-time decisions are required to achieve drilling objectives with minimum cost.
This paper demonstrates a new approach to updating an integrated reservoir model in near real-time, both structurally and petrophysically, to optimally geosteer wells through the most productive zones of the reservoir. The proposed workflow assumes the availability of pre-built geological models populated with at least a porosity attribute. Instead of relying on quick-look effective porosity logs, which are subject to many unknown parameters, we present a new methodology to convert porosity models to gamma ray models which can be more easily correlated with the LWD gamma ray log. This minimizes the number of computational steps required to update the model, resulting in faster model updates.
To further accelerate model update, models were sectored (cropped) around the active well. Sector boundaries need to be carefully selected to honor the influence of adjacent wells during krigging. Smaller models allow increased horizontal and vertical resolution, to approximate the well log resolution, without impacting compute time. This high resolution model is then populated with the full field petrophysical properties and used for geosteering. The paper concludes by summarizing lessons learned using this approach, the pros and cons, and possible areas for future enhancement.
Managing Total Circulation Losses with Pressurized Mud Cap Drilling (PMCD) During Completion: Case History of Practical Solution
Authors: Hajiyeva Madina , Osuji-Bells Godwin A. , Rozlan M. Rizwan , Samuel Orient B. , M. Zulkhairi Zahari , Upadhyay Abhishek , Buch Manish 
Published: March 2016

Abstract
Completing well in a carbonate formation is often a big challenge due to occurrence of severe losses in highly fractured limestone formations. In some cases, total losses might lead to prolonged operation time and/or well abandonment with attendant cost implications. Traditionally, Loss Circulation Materials (LCMs) are used to combat losses before completion operation commences. However, there have been limited success with this approach especially in this case where Karst was encountered.
Originated under Managed Pressure Drilling (MPD) system, Pressurized Mud Cap Drilling (PMCD) with continuous seawater injection was introduced in XT Carbonate Oil Development Project. Due to the subnormal formation pressure, seawater was injected continuously down the annulus to maintain the hydrostatic pressure of the hole while ensuring that no formation fluid or gas entered the well bore. By injecting at a rate higher than the loss rate, an artificially induced surface pressure allows for wellbore monitoring while completion assemblies are being deployed.
Prior to running in Lower Completion, a composite bridge plug was set at deepest possible location in production casing instead of the conventional Downhole Deployment Valve (DDV) resulting in the savings of about USD 1 Million. Some modifications were made on initial completion string whereby a sacrificial motor and a bit were included in Lower Completion string design. With the well in static mode, this modified lower completion string which consists of mud motor, drill bit and pre-drilled liner was used to drill out the bridge plug effortlessly. PMCD mode with continuous sea water injection was activated once the plug has been drilled out and while Lower Completion string was run to Total Depth (TD). After setting the Liner Hanger Packer and closing Fluid Isolation Valve, the well was back to static mode and ready for wellbore cleanup and upper completion runs.
Five (5) high temperature wells have been designed employing the above technique which resulted in significant savings in rig time and cost as well as formation damage reduction and increased operating efficiency. This paper summarizes the practical experiences gained during the planning and deployment of lower completion string with perforated liners in a total losses condition with PMCD .
Successfully Managing NPT in a Deep, Deviated, High-Temperature Interval in Kuwait by Bridging Hole-Enlargement Technology and Drilling Efficiencies
Authors: Elberr Ahmed Sameer , Helmy Hesham , Okorie Onochie M , Stringer Jordan , Muselhi Ahmed , Khattab Sameh , Al-Mutari Bandar , Abdelhafiz Hassan , Kumar Akshaya , Gazi Naz H. 
Published: March 2016

Abstract

Objectives/Scope
With ever increasing well construction challenges associated with lithology, downhole temperatures & pressures, the need for high performance concentric hole enlargement has never been more essential to meet the clients well objectives. Hole Enlargement portrays an area of concern by multiple oil & gas operators due to the challenging nature of enlarging a hole that subjects the tool & string members to aggressive dynamic vibrations especially when combined with thermal stresses and unpredictable lithology.

Methods, Procedures, Process
While drilling a challenging deep development well in Kuwait, the drilling engineers considered enlarging a 2,000 ft 6 inch horizontal interval to 7 inch (17% beyond the bit diameter) to facilitate 5 inch liner being run to TD & mitigate restrictions which have resulted in significant NPT due to a 50% shale & 50% lime stone unstable interval. Drilling that section has encountered multiple issues associated with the high downhole temperature in terms of directional drilling motor failures costing the operator 4 tripping cycles to replace failed tools.

Results, Observations, and Conclusions
Defining a hole enlargement operation using a hydraulically actuated underreamer in such challenging well was supported through an extensive application engineering feasibility study from both the service provider and operator, initiating from an operational risk assessment, hydraulic optimization simulations to ensure maximum cooling and cutting delivery efficiency, Torque & Drag analysis, vibration and critical speed interpretation, stuck pipe simulations to effectively analyze jar placement performance. The underreamer was successfully operated in downhole temperatures exceeding 300 degrees Fahrenheit and the 2000 ft interval was enlarged in 2 trips. Additional PDC cutting structure work-rate modeling was utilized to optimize the positioning of the PDC cutters for an enhanced cutting efficiency in addition to real time field support that provides drilling parameter recommendations for weight on reamer, RPM, & ROP for the entire interval to mitigate additional trips and improve drilling efficiency.

Novel/Additive Information
Enhancing drilling efficiency while managing NPT was the defined objectives for both parties while initially designing a hole enlargement application engineering package. This was successfully implemented and saved the operator 3 days of rig time on the planned drilling time.
Managed Pressure Drilling Application to Deploy Lower Completion Safely and Efficiently in Static-Underbalanced Well
Authors: Agustinus Krisboa , Zein Joydi M. , Irawan Fikri , Wuest Chad 
Published: March 2016

Abstract
Completion phase is critical in well construction where drilling operation is achieved in static-underbalanced condition with water as circulation fluid. With utilization of Managed Pressure Drilling (MPD) equipment that consists of Rotating Control Device (RCD), Automated MPD Choke Manifold, and Downhole Isolation Valve (DIV), lower completion string can be deployed safely and efficiently. MPD technique enables safe and efficient transition after reaching target depth and prior running lower completion. The same technique allows instant and manageable bottom hole pressure upon the completion phase.
This paper emphasizes the main benefits of MPD technique while running lower completion in a gas-rich well in South Sumatra. With static-underbalanced fluid presence while drilling to target depth, transition from drilling to completion phase is very crucial. The presence of DIV eliminates the needs to kill the well with heavier mud and chemical additives prior tripping out drill string to surface. DIV isolates the open-hole formation safely while drill string is pulled out and lower completion string is made up on surface. This result in easier fluid management on surface by keeping fresh water as circulation fluids, while avoids chemical settling to the pay-zone which can lead to well productivity issues.
While running the completion string, prior to reaching DIV depth, RCD bearing assembly is installed to enable closed-loop and pressure-able drilling system. The DIV is then opened securely while MPD Automated Choke Manifold manages the desired bottom hole pressure by adjusting the surface back pressure accordingly. Although the fluid weight in the well is static-underbalanced, the bottom hole pressure is managed to be overbalance at all time. Lower completion string is run to bottom then its hanger and packer set subsequently to have the primary well barrier in place for further production purpose.
South Sabah Synergy
Authors: Sukiman S. 
Published: March 2016

Abstract
South Sabah operations consists of two major players namely PETRONAS Carigali Sdn Bhd (PCSB) and Talisman Malaysia Ltd. (TML) of which both are operating in close proximity and codependent by design. Driven by an innovative Petroleum Arrangement, integration between PCSB and TML is inevitable in pursuing synergy within the South Sabah area. The accomplishments achieved shall be a role model for other operators to emulate.
A formal steering committee, South Sabah Synergy Group (SSSG), consists of senior representatives of PETRONAS, PCSB and TML was established with a role to direct and oversee series of working groups. The coordination was made possible by a Joint Asset Working Group (JAWG) which put forward specific opportunities for deliberation and deliver a comprehensive list of synergies. This was done through identifying all opportunities purely on technical prospects and for each of the opportunity, a preliminary analysis of its potential benefits and risks were done followed by capturing all plans that were essential to its realization. Lastly, the identified opportunities were ranked and assessed based on impact against do-ability and the ones identified as "low hanging fruits" became the main focus area.
A potential savings of USD 30 million to USD 50 million are expected over the Production Sharing Contract (PSC) life. This was evident from two years' worth of achievements (1) spare parts sharing has saved USD 200,000, (2) subsurface data sharing has saved USD 3.0 million on core samples acquisition, (3) sharing of drilling rig mobilization has saved USD 1.4 million and accelerated the project by 30 days. In the mid-term opportunities; (1) logistics sharing will save USD 520,000 a year and increase 50% boat availability, (2) a 5-year integrated planning will optimize production downtime and (3) streamlining emergency response will result in an effective and well-coordinated response. The list goes on beyond current scope and vicinity and further opportunities can be realized within the wider Sabah network.
The key success factor is to streamline the mindset and perspective between all parties to focus on win-win strategy by understanding that the ultimate goal of fulfilling synergy will translate into increasing profitability in the most efficient way.
Low Pressure Production Unit LPPU
Authors: Thiruthonder H. , Jothy A. 
Published: March 2016

Abstract
With soaring global demand, depleting supplies of crude oil coupled with the collapse in the oil prices, maximizing oil production in mature fields has become a priority. Such fields account for over 70% of the world's oil and gas production, with a worldwide average recovery factor of 35% for oil. Main challenge encountered by mature oil fields is the well pressure depletion over time. Since pressure depletion is inevitable, it is particularly challenging to continue to produce as there is insufficient reservoir pressure to push the well fluids to the main processing facilities.
The system discussed in this paper is an effective engineering solution designed for topside receiving facilities. The Low Pressure Production Unit ‘LPPU’ is a separation system for boosting the pressure of production fluids from low pressure wells. It is ideally suited for remote wellhead platforms where wells have insufficient pressure to deliver well fluids to production header, space is a constraint, and manning is not required.
Conceptual design of this system is based on the very low, almost atmospheric, operating pressure of the system, wherein the flow from the well to topside becomes easier without the need to inject the well itself with any foreign elements. The system is designed in such a way that it can receive continuous full flow from the well, and still manages –through intricate isolation methodology- to operate in batches. This batch operation arrangement allows for liquid accumulation which is then discharged to the production header after being pressurized.
System adopts different variations based on availability; it either uses HP gas -typically from existing gas-lift compressor from the main processing platform- or compresses the associated gas from the FWS to be used as ‘motive gas’ which is used to pressurize and push down the accumulated liquid towards the delivery of flow to the production header.
A characteristic optimization factor that contributes greatly to the economic and operational attraction of this system is its ability to utilize its equipment to combine solutions for the two challenges of 1-reduced pressure that's beneficial to the well flow, and 2-the higher pressure essential for the production header.
Straits of Malacca Exploration Campaign - Lessons Learnt and Key to Success
Authors: Yoong William Liew Sin , Azmi Fadzliana , Rahim Azral A , Ghani Syazwan A , Idris M Faisal Rizal , Idris M Ramdan , Ibrahim W M Syazwan W , Rahman Hamdan Abd , Sawal M Rizal , Wan Terrence Lawai 
Published: March 2016

Abstract
Straits of Malacca Exploration Campaign marks PETRONAS' first oil/gas well drilling in the region of West Coast of Peninsular Malaysia. Three (3) exploration wells were drilled in a period of four (4) months. This paper will highlight the challenges, lessons learnt and key to success of this fast track drilling campaign in a new region of operation.
The team which was entrusted with the mission to drive PETRONAS' quest of oil and gas in this new region were then given six (6) months to deliver the first well out of three (3) exploration wells. Apart from the uphill task to set up staging base and logistics support in the West Coast of Peninsular Malaysia, the team faced challenges of drilling in one of the world's busiest shipping lane. Navigational safety is one of the main concern here. Besides, two (2) of the three (3) wells were located close area where sea robberies and hijacking were rampant. In terms of drilling operation, two (2) of the wells were exposed to the risk of total losses. This paper will share the approaches taken by the project team in overcoming challenges in three (3) main areas - (1) logistics; (2) navigational and offshore safety and security; and (3) well engineering.
Although faced with numerous challenges together with limitation of time and resources, the project team has managed to deliver all the three (3) wells successfully, meeting all the geological objectives within Authorisation For Expenditure (AFE) cost. On top of that, the drilling campaign was completed with zero Lost Time Incident (LTI) and zero accident. Another notable success in this project is setting up the modus operandi in a new region of drilling within six (6) months. Due to the fast track nature of this campaign, first of the three (3) wells was spudded concurrently with 3D seismic interpretation by taking the risk of relying on 2D seismic data. Halfway through the well construction, Well #1 (Well A) was re-sanctioned based on the findings while drilling and latest 3D seismic data received. Target depth of the well was revised to 3130m TVDSS from initial 2100m TVDSS. Despite all the challenges, the drilling team managed to complete drilling operation of three (3) wells ahead of time by 11 days in total.
Apart from engineering and logistics challenges, this paper will share the experience of drilling in one of the busiest shipping lanes in the world. Lessons learnt and key success factors of this fast track exploration drilling campaign will be beneficial to all oil and gas (O&G) operators, especially to those planning to operate in the Straits of Malacca or any other similar regions in the world.
Managing Constant Bottom Hole Pressure with Continuous Flow Systems
Authors: Riddoch James , Wuest Chad , Toralde Julmar Shaun S. 
Published: March 2016

Abstract
Managing downhole pressure and temperature is critical, particularly in deepwater, high-pressure, high-temperature (HP/HT), extended reach drilling (ERD), and other challenging operating conditions.
A large percentage of all drilling hazards related to wellbore pressure occur when mud pumps are cycled off and on during connections, causing fluctuations in equivalent circulation densities (ECD) and downhole pressure and temperature spikes. These conditions can result in expensive downtime, safety issues, and the inability to drill a well within extreme scenarios.
Continuous flow system (CFS) technology mitigates the hazards of wellbore pressure drilling even while mud pumps are cycled off and on during connections. Unregulated, these cycles can cause ECD fluctuations and downhole pressure spikes. The system ensures constant bottomhole pressure. This variant of Managed Pressure Drilling (MPD) can reduce expensive downtime, minimize safety issues, and enable safe and efficient drilling in otherwise undrillable wells.
This technology can enable the drilling team to decrease nonproductive time by providing continuous circulation, which improves hole cleaning and maintains ECD.
Test results of the use of a continuous flow system under development reveal that the system can maintain bottomhole pressure constant consistently and continuously.