bluuebunny/crossref_metadata_2025_split huggingface dataset:
Application of Lean Principles to Accelerate Project Development
Authors: Tønnessen Roger , Byrnes Richard , Franco Miguel , Romaine Keith 
Published: March 2015

Abstract
Oil and gas project development in the North Sea is known for large discoveries, requiring the need for highly complex, capital intensive infrastructure, which can take decades to complete. Recognizing that such discoveries were becoming less common, a faster and less capital intensive approach was needed to develop smaller fields. The idea was to target fields close to existing infrastructure that could tie back to current installations and only require a seabed template. Historically, these types of projects would take the company over five years to complete. A dedicated team was established to plan these smaller projects, appropriately called “Fast Track” projects, and was challenged with cutting development time in half.
The Fast Track team used lean principles to analyze project lead times and target improvement opportunities. Lean is a methodology made famous in automotive manufacturing, which seeks to eliminate time wasting activities and reduce overall lead time (De Wardt 1994). The primary lean technique employed by the team was value stream mapping. First, the team mapped out the entire project development process, from discovery to production, and identified all the key steps in the process. Second, the team estimated the time it takes to perform each major step in the process and calculated the total lead time for project development. Finally, the team quantified all the sources of delays and developed opportunities for improvement. These opportunities were then ranked based on the potential time and cost savings. With the prioritized opportunities, an improvement road map was developed to steer the team in the right direction.
The improvement road map contained a four-pronged approach to cut project development times in half: StandardizationCollaborationStreamlined processesChange management
Standardization involved developing standard subsea templates, well designs, and completions equipment to cut the time to develop solutions. Collaboration involved integrating the operator and the service company and making use of teams in different time zones to accelerate well design and planning. Streamlined processes focused on combining decision gates in capital projects and working the well construction process in parallel to the project development process to reduce planning time. Finally, change management involved establishing a continuous improvement process, a system to implement ideas and engrain them into the organization, and a common set of key performance indicators to align different stakeholders and drive execution results.
Implementation of these improvement opportunities led to a reduction of over two years in the time needed to complete the development projects: from 5.3 years to an average of three years.
'Engineering' Design of Lost Circulation Materials (LCMs) is More than Adding a Word
Authors: Savari Sharath , Kulkarni Sandeep D. , Whitfill Donald L. , Jamison Dale E. 
Published: March 2015

Abstract
Curing lost circulation, one of the greatest contributors to drilling non-productive time (NPT), predominately has been addressed by applying particulate lost circulation materials (LCMs) into drilling fluids. Selection of LCM combinations has largely been based on experience and driven by the availability of inexpensive materials on location. With respect to lost circulation control, little time has been invested into engineering the LCM design and the subsequent effect on rheology and suspension properties of the drilling fluid. Also, little to no information is published regarding methods or guidelines for designing LCMs for lost circulation applications.
Continuing the effort for better lost circulation treatment design, a holistic engineered approach to designing LCMs for mitigating lost circulation is discussed. Depending on the type of flow path (e.g., formation pores and natural or induced fractures), engineering methods and models are presented for the selection of LCM combinations with an appropriate particle-size distribution (PSD) capable of efficient fracture plugging. Models to estimate the effects of LCM addition on drilling fluid rheology and equivalent circulating densities (ECDs) are presented. For some applications, it is critical to have the LCMs suspended properly in the drilling fluid. A unique LCM suspension model is presented that estimates the optimum drilling fluid rheology required for proper suspension. This model is capable of accommodating any changes in drilling fluid density as well as LCM density, size, or concentration.
This holistic engineered approach, when considered during the initial drilling fluid planning phase, can be a valuable engineering tool for engineers when preparing a plan for preventing or curing lost circulation. The effort to bring engineering to LCM design should result in large savings in terms of NPT, which directly translates to reduced cost and more efficient use of available drilling rigs. This paper also presents some guidelines for designing and testing LCMs for lost circulation applications.
Advanced FEA Modeling Delivers Solution for Designing a Dual Hole Opening BHA for a Single Directional Run
Authors: Najmi Nik Fahusnaza , Soh Azrin , Nair Divya G. , Zaim Muhammad Afiq , James Biju , Subroto Bramanta , Omar Taufik 
Published: March 2015

Abstract
Drilling the 8½” x 10-5/8″ x 12¼” S-shaped wellbore through soft unconsolidated formation and highly compartmentalized reservoir offshore East Malaysia is exceptionally challenging. Previously, the operator has drilled a similar hole opening section in this marginal field with two separate runs. The directional requirements combined with low WOB took the operator three days to drill and open the 640m section. For the new drilling campaign, the reservoir objectives were to drill deeper and to appraise the well, with an option to complete and produce the gas reservoirs if there are any discoveries. The operator requested the hole be drilled with hole enlargement while drilling (HEWD) tools in a single run, with real-time logging tools. This technique would eliminate the requirement for extra 8½” pilot hole thus significantly reduce rig-days.
Designing a robust and durable BHA for the 1370m long directional run demands intricate planning. To ensure the three cutting structures would synchronize and work in harmony, a pre-job FEA-based modeling system was used to investigate the dynamic drilling behavior of the BHA. The results of simulations from the initial BHA predicted very high vibrations which could potentially result in tool damage. A BHA optimization analysis was then conducted to enhance the BHA design to eliminate vibration issues. The simulation results of the optimized BHA design exhibited measurable reduction in vibration levels.
The operator implemented the recommended BHA and a total of 1371m was successfully drilled and opened in one run, in just four days. All directional requirements were met and a good set of survey and log data was transmitted up the well without issues. Compared with the traditional two run approach, the single run yielded a 25% time savings to the operator. No vibrations were recorded and the BHA was pulled at section TD with no significant wear on the three cutting structures. There were no issues running casing, which implies good borehole quality.
Extending Bit Life Through Bearing Innovations
Authors: Schroder J. , AlDarwaish A. , Richards J.W. , Pasquale M. Di , Mohamed M. , Yorty Jesse 
Published: March 2015

Abstract
This paper describes how recent tapered bearing innovations in rock bits have significantly increased the life of the roller-cone bit, including advanced systems analysis and an endurance record set with a recent onshore exploration run in the Middle East. This record run beat the field average by over 70% in bit revolutions and 58% in footage. One of the primary constraints with roller-cone rock bits has always been bearing life. Traditional journal bearings and cylindrical roller bearings with ball-lock cone retention result in inherent play in the system, reducing bearing and seal life. As a result, this reduces overall bit life and directly affects drilling cost through increased trips and additional drill bits needed to complete a section. Recent innovations have been made to effectively package application-specific tapered bearing technology into roller-cone assemblies. This system provides a preloaded bearing package, eliminating the damaging axial and radial play found in rock bits today. In addition, the system stabilizes the sealing interface between the head and cone, promoting extended seal life. Analytical modeling was utilized to define and simulate many different loading conditions that could be experienced downhole including reaming, up-drill, directional drilling, and high weight. Through the use of proprietary bearing analysis software, optimal bearings were developed to perform effectively across the broad range of potential loading conditions. The result is an innovative, new bearing assembly, specifically developed for rock bits, that enables significant increases in the service life of bits using roller-cones. This paper will describe real-life advantages of this technology and how it is being implemented into the drilling industry.
Managed Pressure Cementing Enables Offshore Operator to Reach TD in Narrow Margin Ultra-HP/HT Well in Malaysia
Authors: Tan Brendon , Gillies James , Noh Aizat , Mohamed Khairul Anwar , Wahid Farid , Bordessoulles Willy , Jain Pankaj 
Published: March 2015

Abstract
This paper discusses the experiences and good practices established from successfully executing two managed pressure cementing (MPC) jobs within an ultra high-pressure/high-temperature (HP/HT) well in offshore Malaysia.
The risks associated with cementing in sections with narrow margins between pore pressure and fracture gradient can often limit the length of each cased section, hence limiting the final total depth (TD) of the well. A new cementing technique using managed pressure drilling (MPD) equipment and processes allows the wellbore to be displaced with a hydrostatically underbalanced mud after the casing string has landed and then cemented with a hydrostatically underbalanced spacer and cement slurry.
This technique was used to successfully cement an 11 3/4-in. intermediate liner and a 9 7/8-in. production liner, which, in turn, enabled the operator to reach the target depth. The 11 3/4-in. liner was cemented successfully without losses or gains, despite only a 0.2-lbm/gal window (15.6 to 15.8 lbm/gal), with bottomhole static temperature (BHST) of 133°C. This job was executed with a 15.0-lbm/gal mud, a 15.0-lbm/gal spacer, a 15.0-lbm/gal cement slurry, and up to 400 psi surface backpressure (SBP). The 9 7/8-in. liner was also cemented successfully without losses or gains with a 0.9-lbm/gal window (17.4 to 18.3 lbm/gal) with BHST of 163°C. This job was executed with a 17.0-lbm/gal mud, a 17.0-lbm/gal spacer, a 17.0-lbm/gal cement slurry, and up to 600 psi SBP. A cement bond log (CBL) was run for the 9 7/8-in. production liner and the results showed good bonding across the entire openhole section, including the critical target zones. The prejob engineering and execution involved extensive hydraulic modeling, closely coordinated with the MPD service provider, and comprehensive risk analysis and mitigation plans.
A Model for Well Reliability Analysis throughout the Life of a Well Using Barrier Engineering and Performance
Authors: Das Bibek , Samuel Robello 
Published: March 2015

Abstract
Maintaining well integrity and preventing loss of containment throughout the life of a well is of prime importance. This is achieved through effective and efficient operations of primary and secondary barriers. Barrier resistance and performance can change over the life of a well because of loads induced by different operations and changing well conditions. Well reliability is a key performance indicator of barrier effectiveness.
The conventional reliability calculation defines total system reliability as the probability of barrier success, or 1- the probability of barrier failure (i.e., probability that all barriers to uncontrolled flow along a particular path will fail simultaneously). However, this definition does not account for the changes in the barriers' effectiveness with time. Although such changes are accounted for during engineering calculations (i.e., design loads), conventional reliability calculations do not reflect the engineering assumptions and calculations in barrier design. Also, the reliability calculations do not account for different operations and the stresses they impose on the barriers that can speed the time-to-failure of the barrier.
In this paper, the integrity of casing as a secondary barrier is studied. To overcome the limitations mentioned, a unique well reliability model is proposed. The reliability in this model depends on individual elements, such as casing design and ratings, as well as the conditions found in the well at the time of running and cementing the casing, drilling subsequent hole sections, and during production operations. The proposed reliability model incorporates casing design calculations, any reduction in strength foreseen, and induced loads attributed to drilling operations (casing wear). A simulation program was developed using simulation software The time-to-failure for casing under the generated stress levels was computed using an accelerated test model developed using an engineering simulation software. The results show what happens when equivalent stress or von Mises stress are applied as failure criterion and acceleration factors are applied to the accelerated test model. The three failure modes considered were collapse, burst, and failure under tensile load.
Further, the Weibull distribution function is used to fit various shapes of reliability curves. A comparison of probability distribution curves of the casing capacity and the loads generated are presented in the results. A “stress modification factor” is introduced in the set of reliability equations to incorporate change in barrier performance attributed to changing conditions. Das and Samuel (2014) introduced the concept of reliability-informed drilling and a model for estimating dynamic reliability. This paper goes further in using the dynamic reliability concept and shows changing well reliability as a function of its changing barrier effectiveness, estimated over the entire life of the well.
Case Study: Tapping into Corporate Domain Expertise Using a Standard Realtime Data Solution
Authors: Regan Matt , Kucs Richard 
Published: March 2015

Abstract
This paper describes how a major European independent Operator, with a wide range of operating assets spread across the world, each with its own set of unique drilling and logistical challenges, has made the strategic decision to implement a realtime data management architecture supporting their entire global organisation by partnering with a vendor-neutral data management specialist to deliver a bespoke enterprise-wide solution.
The Operator mandated that at all stages the solution needed to be a common framework fit for purpose from Norway to New Zealand, from pastoral fields to desert war zones.
The paper will cover all aspects of the project through conceptualisation and functional needs assessment, technical qualification, infrastructure at rigsites and offices, data hosting and quality assurance, use of industry standards, change management and workflow design, benchmarking and key performance indicators (KPIs), and finally deployment and integration into daily operation.
Historically, the Operator had been reliant on realtime decision-making in local offices being made almost autonomously, with secondary input from the Operator's head office referenced secondarily, occasionally, and often after the event. The absence of a standard realtime data exchange solution was recognised as an impediment to efficient, collaborative use of the substantial drilling domain expertise distributed throughout the organisation.
Having invested in a corporate realtime drilling data infrastructure, the Operator now derives full value of their global knowledge base being made immediately available to any operation at any time, irrespective of location. Truly collaborative, timely, informed operational decision-making now drives performance improvement, risk and cost reduction, and optimised well delivery.
A Case Study of Flexible/Expandable and Self-Healing Cement for Ensuring Zonal Isolation in a Shallow, Hydraulically Fractured Gas Well, Onshore Thailand
Authors: Bermea J.A. Vargas , Taoutaou S. , Olutimehin K. , Vinaipanit M. , Ashraf S. , Segret G. , Asawakowitkorn J. , Kongpat N. 
Published: March 2015

Abstract
Cementing design and execution is key to achieving zonal isolation for safe and economic well production. The critical goal of long-term well integrity is a fundamental element of any well construction strategy especially when the well will be subject to cyclic loads and changing downhole stresses e.g from stimulations operations. Exploration and appraisal wells pose an additional challenge because many formation-specific parameters relating to the field may not be fully understood.
This case describes the use of self-healing cement and flexible and expandable cement to optimize isolation and ultimately, well delivery on a critical exploration well project for a National Oil Company. Globally, self-healing cements have been increasing used in the last decade and this was the first application for this operator onshore Thailand. The self-healing cement system was used as a secondary barrier in the well in the case of cracks or deformation within the primary cement matrix. The combination would serve as a more robust solution to mitigate the impact of stresses generated during different well lifecycle phases. The design principle of self-healing cement is the ability to swell upon contact with hydrocarbons to restore well integrity.
Upon installation in the well, cement evaluation logs and the physical indications showed that zonal isolation had been completely achieved for the entire production interval. In addition, no sustained casing pressure was experienced after the hydraulic fracturing operations were performed. Health, Safety & Environment (HSE) concerns were addressed ensuring no hydrocarbon gas leak to surface and no contamination of underground water zones.
Faster ROP in Hard Chalk: Proving a New Hypothesis for Drilling Dynamics
Authors: Akutsu Eirik , Rødsjø Mads , Gjertsen John , Andersen Mats , Reimers Nils , Granhøy-Lieng Morten , Strøm Ellen , Horvei Kjell Arvid 
Published: March 2015

Abstract
A well documented path to improving overall efficiency in project execution is through an integrated team approach which involves both the operator and the service suppliers. This paper describes what can be achieved when such a team adopts a fearless approach to new technology, and dares to think outside existing conventions. To be more specific, the paper covers the engineering, planning, and execution of a HTHP exploration program in the central North Sea by a Norwegian operator.
Large areas of the North Sea contain the Cretaceous period of sediments which comprise of a massive hard layer of chalk that historically has posed a major drilling risk and expense to operators in the area. To mitigate expected problems an integrated team was gathered to thoroughly analyze drilling records and lessons learned from previous offset wells and re-engineer the drilling process with the aim of minimizing cost and uncertainty when drilling the most challenging chalk interval.
The paper presents the hypothesis that formed the basis for the team effort, and the measures implemented based on said hypothesis. This includes an unconventional bit selection and the use of modern vibration measurement technology and mitigation techniques, as well as a key electro-mechanical modification of the advanced logging and directional suite completed by the lead service provider. The discussion and reasoning behind each step is included and the method was repeated in several wells with the same results, verifying the validity of the findings and making the paper a valuable input for drilling hard chalk.
The nominal result from applying the new methodology was a doubling of the rate of penetration (ROP) in the harder layers, and the entire section of problematic strata was drilled in one single bit run. Drilling time was reduced by 12 days when compared to average figures from recent offset wells representing an estimated cost saving of 15 - 20% on the overall well budget. The method and savings presented are primarily of interest to stakeholders in the central North Sea, but can also be applicable to other areas with hard chalk and stringers with similar characteristics.
All-Attitude Gyro While Drilling Technology Provides Accurate Surveys in High Angle East/West Directional Wellbores Delivering Reduced Costs and Increasing the Length of the Producing Zone
Authors: Beattie Keith , Shoup Rob , Weston John , Burke Peter 
Published: March 2015

Abstract
The accurate placement of directionally controlled wellbores is essential in order to maximize oil production while avoiding collisions with existing wells. Error models provide estimates of the positional uncertainty that can be expected when using a specific survey tool. For example, a Measurement While Drilling (MWD) tool will have a different ellipsoid of uncertainty when compared to a Gyro While Drilling (GWD) or a continuous gyro tool. Whichever survey tool is chosen, the uncertainty in the calculated wellbore position is dependent on the trajectory and latitude of the planned wellbore. Many drilling projects have been designed assuming specific survey instruments and favorable drilling directions. However, these assumptions are often not fulfilled due to existing wellbores, environmental safety concerns, land management issues, drilling costs and survey tools available. Different azimuthal corrections and methods of surveying have been deployed to increase confidence in the wellbore placement when drilling wells in east or west directions at high inclinations. MWD surveys with magnetic interference corrections and rate-gyro surveying on wireline are two examples of these methods. Previous GWD technology was limited to 70 degrees of inclination and was not an option for high angle and horizontal wells. With the development of an all-attitude GWD tool, it is now possible to provide accurate gyroscopic surveys at all inclinations and all directions during the drilling process in real time.
This paper describes a case study in which the all-attitude GWD tool was utilized to achieve tighter control of well trajectories drilled predominantly in an easterly direction in close proximity to a number of existing wellbores. This approach allowed a significant reduction in costs since it became possible to drill all the wells from an existing pad and so avoid land management and environmental concerns initially associated with the project. Further, the accuracy of an all-attitude GWD tool allowed the operator to drill safely through an additional 1,000 feet of geological pay zone, a result that could not have been achieved safely using MWD surveys alone.