bluuebunny/crossref_metadata_2025_split huggingface dataset:
ADCO New Rigs Start Up Project: Increasing rig fleet and activities by 30%, Challenges and Lessons learned
Authors: Mohamed Mohamed Hussain , Hussain Mohamed Qassem , Carvalho Rui , Kuyken Chris 
Published: October 2013

Abstract
Abu Dhabi National Company for Onshore Oil Operations (ADCO) is expanding their operation in terms of increasing the production quota by drilling more wells with working over the existing wells. Therefore, the demanding to increasing rig fleet and activities is one of the important milestones in Drilling Division in ADCO. It is very critical and complex challenging to mobilize and start up with new drilling rigs. This process have an impact of a high cost and risk to any Oil and Gas company's business, so all the mitigations and risks should carefully be observed, taken and planned ahead prior each stage of ADCO New Rigs Start up project.
Three main stages are considered after defining the specifications of the required drilling rigs. They are (1) construction, (2) commissioning and (3) start-up. Different risks and Challenges involved in each stage of the ADCO New Rigs Start up project process such as delays during any stage of the project which have a great impact on delivering the rigs as per the planned frame work therefore, delays in delivering the company business plan.
This paper will express the challenge of having delays causing high impact in company business plan, however, the higher risk is always safety related. In addition of illustrating safe start-up is always considered the priority and focus through all project stages for achieving Zero-Harm target.
Creating a Global Wells Institute inside a Major Operator
Authors: Williamson H. S. , Jones N. 
Published: October 2013

Abstract
This paper describes how a major international oil and gas company is creating a distinctive internal solution for staff capability development - a ‘global wells institute’ - via a three-fold transformation of learning. First, a progression of development ‘roadmaps’, covering technical, management and leadership skills, is designed to provide career-long continuity in professional development. Second, individual progress will be defined by the successful application of skills, with transfer of learning from the classroom to the workplace being formally supported by line managers and a global coaching programme. Third, a systematic performance consulting process will inform a performance improvement cycle, and keep the global wells institute aligned with evolving business needs.
This approach is attractive from the point of view of the learner, contributing to an ‘institute experience’ which is challenging, engaging and rewarding. From a systems perspective, the approach makes the development of people more systematic and controlled.
Similar criteria are being used to select the facilities, technology and instructional practices which will support the global wells institute. On one hand, choices are based on rigorous learning needs and performance analysis. On the other, the end-result inspires those who use the institute - learners and faculty - in the development of themselves and their colleagues. The global wells institute delivers a 21st century capability development solution.
New Vertical Drilling System Brings Real Time Survey and RSS Performance While Reducing Overall Operating Costs
Authors: Neil P. , Herrington D. 
Published: October 2013

Abstract
As the depth and horizontal reach of oil and gas wells is extended further each year, the importance of maintaining a truly vertical top section becomes more and more critical. Today, limited solutions are available to manage this challenge, as with all conventional methods either cost or quality must be compromised. A more financially viable solution must be provided for the drilling industry to continue the pursuit of hydrocarbons in these increasingly complex applications.
Curves or kinks created by correcting for the natural drift of the bit create additional points of contact through the well's vertical section, creating tortuosity and drag. To maintain true verticality and a straight borehole, drillers have only limited solutions. Control drilling provides slow and limited performance, while bent housing mud motors effectively correct the deviation, but result in increased tortuosity. Excellent performance is provided by Rotary Steerable Systems (RSS), but they are cost prohibitive both in terms of daily costs and the risk of Lost in Hole (LIH) charges.
New technology has been developed that provides the economics of bent housing motor drilling with the performance and borehole quality of conventional RSS tools. By simplifying the mechanical and electronic designs required for steering and supplying autonomous function in the field, this new tool fills the gap between these two systems. Additionally, the tool incorporates real time verticality measurements at a fraction of the cost of Measurement While Drilling (MWD) tools, providing an economical solution that delivers a high quality vertical wellbore while reducing the cost per foot of the well.
By providing autonomous operation with RSS performance, this technology has assisted operators in the Middle East region significantly reduce their vertical section cost per well. This paper will detail how this new system is being used to deliver economic and in-ground performance that bridges the gap between motors and RSS tools. Performance data and analysis showing the value and advantages provided by this unique drilling system will be included.
Advanced Milling Technology Sets Record for Number of Composite Mill Outs for ‘Plug-N-Perf’ Completions in the Williston Basin
Authors: Larsen Adam , Garfield Garry 
Published: October 2013

Abstract
The increasing need to improve production as well as limit the time between fracturing operations and well production in the Williston basin is a key driver in forwarding milling technology in the through-tubing environment. To keep up with advancing completion methods, through-tubing technology has been upgraded to enable an increasing number of composite plugs and ball seats to be completely milled out in one trip reducing downhole time which reduces operator costs. An operator in the Williston basin, after having set 79 composite plugs in two separate wellbores and completed fracing operations in the Bakken shale, was prepared to bring wells online. The removal of 79 plugs in two wellbores normally takes a significant amount of time, and involves several trips downhole and pulling the bottomhole assembly (BHA) to change out worn components. Utilizing a milling-specific application for removing composite plugs, 43 composite plugs in the first well were removed in a single run using a workover rig. The same mill that was used with the first well was sent back to the shop and inspected and used on the second well to remove 36 composite plugs from the second wellbore without redress. Milling a large number of composite plugs in two wells in one trip equalls time saved and significantly reduced cost. The paper describes the operation, the downhole components of the BHA, including the application-specific milling technology, and the cost savings to the customer during the record-setting mill out operation.
Solving Hard/Abrasive Sedimentary and Igneous Formation Challenge: New PDC Bit Design Reduces 6-in Section Drilling Time by 47%
Authors: Peytchev Peter , Malik Sumit D. , Varghese Roy , Doodraj Sunil , Srinivasan Sudarsan , Benny Praveen , Raghav Sanjeev , Narayanan Shine 
Published: October 2013

Abstract
The 6"hole section in Raageshwari Field NW India (onshore) is typically between 600–800m long and highly challenging in terms of formation strength and abrasiveness. Lithology in the upper part is composed of sandstone, claystone and weathered basalt with unconfined compressive strength (UCS) between 3–5kpsi. The lower section contains basalt, felsic and sub-felsic igneous formations with UCS range of 15–30kpsi.
Historically, a two bit strategy was employed. First, a PDC bit on a positive displacement motor (PDM) bottom hole assembly was used to drill the soft 6" section until ROP dropped to an unacceptable level. The BHA was then pulled and followed by a diamond impregnated bit on a turbine BHA to drill the very hard volcanics. Typical average on-bottom ROP for the entire section was 4.5m/hr and took approximately 170 hours to reach total depth (TD).
To reduce costs, new technology was proposed to improve bit durability in the hard/abrasive volcanics and drill the entire 6" section in one run at a higher ROP. Recent bit and drilling data from offset wells was analyzed to assist in developing a new, cost effective PDC design to replace the expensive diamond-impregnated bits and drill the 6" hole section in one run. The study resulted in a new six-bladed PDC bit with 13 mm cutters that incorporates superior cutter technology to improve durability and resist physical and thermal degradation. The design includes a row of backup cutters in the shoulder area to increase radial diamond volume for maximum durability.
The new PDC bits have been run on a motor and rotary steerable bottom hole assemblies and drilled the 6" section on three consecutive wells in Raageshwari field totaling 2328meters with an average ROP of 10.7m/hr. This represents approx. 47% decrease in drilling time compared to that previously achieved by Impreg/TCI bit runs. Typically, the new bits are pulled in re-runable condition. This improved performance has saved the operator approximately six-days of rig time and approximately USD 480,000/well.
Enhanced Horizontal Well Drilling in North Kuwait Boosts Drilling Phase and Achieves Wellbore Cleaning Goals
Authors: Al-Enezi Dakhil , Al-Khaldy Ali , Mubarak Sarah , Takate Yogesh , Al-Mutawa Faisal 
Published: October 2013

Abstract
Promotion of horizontal well drilling started with inflow control device (ICD) completion to boost the hydrocarbon production as per the KOC 2030 strategy. Drilling these wells revealed many technical issues leading to stuck pipe due to improper hole cleaning. The rate of penetration (ROP) in the buildup and lateral sections was erratic. Drilling a pilot hole and performing pipe-conveyed logging runs were the main factors contributing to excess rig time. It was observed that drain hole cleaning methods and drilling time optimization needed to be improved. These factors increased rig time by about 40 while drilling many horizontal wells in the North Kuwait (NK) horizontal operation, adding significant costs to the well budget.
While drilling these horizontal wells, well design was optimized and the drilling team applied the optimized design that increased hole-cleaning effectively, improved ROP and reduced the logging time. The 6⅛-in. and 8½-in. motorized rotary steer-able systems (RSS) and bottomhole assembly (BHA) systems ran for the first time in Kuwait, drilling 8½-in. build section from Mutriba to the Upper Burgan top formation and 6⅛-in. section in Mauddud carbonates has dynamically avoided down-hole tool failures, doubled the average ROP, and reduced non-productive time (NPT). The pilot hole section was designed and drilled in two phases. In the first section a gamma ray tool identified the formation tops. The second section (zone of formation interest) was then drilled using an 8½-in. tool with a triple-combo RSS BHA. This approach reduced the extensive wireline or tough logging condition (TLC) runs and increased ROP by slimming down the borehole size. The hole-cleaning method was modified by combining pumpout techniques with heavy-weighted pills (MW+2 ppg).
This technique was used in horizontal wells, resulting in reduced drilling time and well cost.
A Comprehensive Methodology of Calculating Hydraulic Parameters in Real Time and the Monitoring System
Authors: Zhou H. , Fan H. , Ji R. , Yin D. , Zhai Y. , Ye Z. 
Published: October 2013

Abstract
Deepwater, HTHP and narrow pressure-margin well depend on accurate, real-time knowledge of down hole hydraulics in order to their objectives safely and economically. A comprehensive methodology of calculating hydraulic parameters on the basis of logging data was formulated. It can conduct a real-time calculating and monitoring hydraulic parameters using logging data in the process of drilling. First, according to the problem of non-unified data units and the mode of data sharing, transmission during the well logging data transmission, an integrated new well site software module was developed, which combined the functions of data acquisition, transportation and simulation. This module puts the variability of the well logging equipment, complicity of I/O ports, and specialty of transmission protocol outside the real-time computation module which is efficient and simple. Second, a real-time hydraulic calculation method was established, in which the influence of drilling pipes rotation and annular eccentricity were taken into account. In order to improve the calculation precision, the flow channel both in pipe and annuli was divided into several sections, through which the different diameters of the channels were considered. And in each section the variation of ESD caused by HTHP was considered too. A series of system software for hydraulics calculating and monitoring were developed, which include all common hydraulic model (Herschel-Bulkely, Robertson-Stiff, Four-parameter model and so on). We can not only use this system to calculate hydraulic parameters of bottom hole but also any other position both in annuli and pipe. The application of this system in the Tarim Basin and the Junggar Basin in Xinjiang Uygur Autonomous Region of China shows the system can exactly monitoring hydraulic parameters and runs smoothly with convenient operation. Therefore it can be seen this system can be applied to provide more convenient, fast and precise hydraulics parameters monitoring while drilling.
Case History: Using Triazine Efficiently to Scavenge Hydrogen Sulfide in Coiled Tubing drilling Operations
Authors: Dugar Alejandro A. , Villalobos Mario J. 
Published: October 2013

Abstract
A major operator in Saudi Arabia is currently performing coiled tubing drilling in some gas wells. Fluid returning from well contains a high concentration of hydrogen sulfide (H2S), with an average of 3.0% to a maximum of 8.0% v/v of H2S reported. This gas is partially dissolved in the water produced from the well. The sour water is separated throughout two different vessels, then it is discharged into an atmospheric tank and ultimately into large, open bio-pits that a major operator designed to collect the effluents from the wells.
The composition of the sour water coming from the second separation vessel shows dissolved H2S content as high as 3,500 ppm. The current water treatment to scavenge H2S relies on a solution of iron-gluconate that is injected as a liquid after the second separator, before the water enters the atmospheric tank. However, the volume of iron-gluconate injected is excessive due to stoichiometric reactions.
A field-trial application was proposed utilizing a Triazine-based product as an alternative to the current treatment because Triazine can scavenge twice the amount of H2S as compared to iron-gluconate. In addition, the reaction products are water soluble, which means they will not precipitate into the sludge deposited at the bottom of the bio-pits, avoiding risks of later release of H2S when they are emptied.
The key performance indicators (KPIs) set by the major operator during the field-trial application included the treatment of H2S dissolved to a concentration less than 100 mg/L in the waste water. The sulfide concentration was monitored before and after chemical treatment utilizing the Garret Gas Train (GGT) for sulfides.
A total of 1,930 ft in 3 laterals were drilled, and H2S concentration in the waste water was successfully reduced to the desired levels utilizing the Triazine-based product with fewer volumes of chemical treatment.
Fuelling the Talent Engine at the Start of the Season
Authors: Currey Sharif , Drenth Harm , Tinkhof Rob , van Beelen Norbert 
Published: October 2013

Abstract
Iraq is taking a radically fresh approach towards developing local talent. Instead of setting high quotas for employing local staff, Iraq has established a mandatory annual investment through a Training, Technology Transfer and Scholarship Fund (TTTSF) as a condition of awarding oil and gas contracts. This money targets building broader Iraqi capability in the industry as opposed to an individual company's staff. This approach overcomes the economic struggle between early project spending versus developing the essential local skillpool required for sustained project success - essentially fuelling the talent-engine at the start of the season.
Shell Iraq Petroleum Development (SIPD) is paving the way by committing a portion of its annual TTTSF investment towards rolling out the first part of its Wells graduate training programme in its Majnoon operation in Southern Iraq. Dedicated recruitment and training staff are developing local Iraqi talent through a two-year programme culminating in a standardised assessment by Shell's Learning and Development team in The Netherlands. A pilot programme was started in February 2012 and the programme has been extremely successful to date. A second intake started in October 2012 and futher intakes are planned for 2013 and 2014.
This programme builds industry capacity in Iraq and is the key to SIPD's Wells succession plan. If a similar approach to early development of local talent were replicated across the industry in Iraq, it stands to revolutionise Iraq as a regional talent hub.
This paper outlines the main challenges faced in rolling out a structured Wells graduate training programme in the early development of the Majnoon field and describes how the challenges were overcome. An overview of the progam's success to date, current status and a forward-looking summary of the SIPD Wells Team's Iraqisation effort is presented.
Strategies for Maximizing Risk Assessment Utility
Authors: Ghoneim Tamer 
Published: October 2013

Abstract
In many instances, the execution of hazard analyses and risk assessments has become an exercise in completing a tall stack of worksheets to fulfill a project milestone, satisfy a client, or proceed quickly with a process or operational change. In many other instances, the risk assessment process may be completely omitted due to lack of knowledge or pressing project/operational need.
Organizations that approach risk management in this manner have the potential to unknowingly accept significant risks to the safety of employees, the environment, and to the reliable operation of their equipment and facilities which can lead to substantial financial loss and damage to brand and reputation.
In offering solutions and approaches for maximizing risk assessment utility, a review of the fundamental purpose of conducting hazard analyses and risk assessments is warranted. A general definition of the key terms, hazard analysis and risk assessment are provided below.
Optimum Lower Completion Design and Implementation for a Highly Fractured Carbonate Reservoir
Authors: Madan Mohammed A. , Mohamed Gad Yasser A. , Vicario Roberto , Galimzyanov Artyom , Gohari Kousha , Gavioli Paolo 
Published: October 2013

Abstract
The most challenging aspect of reservoir management in a highly fractured carbonate reservoir is determining a completion that has the ability to control the production flux and prevent early unwanted fluid breakthrough while maintaining the production. Throughout the years, Saudi Aramco has made much advancement in the field of reservoir optimized completions, by continuously implementing new technology and techniques that enhance the design and deployment of these completions.
When designing an ICD completion, it is critical to design a completion that is best able to provide production flux control while meeting production requirements, as well as considering key operational factors such as, safety, cost and the time required completing the design.
On a recent well in Saudi Arabia an ICD completion was designed to achieve an optimum lower completion as well as reducing the safety risk, the overall cost of the completion and achieving a faster deployment time by deploying for the first time in the Middle East a new generation of Inflow Control Devices (ICD) in a work-over well.
The new ICD contains several unique features, such as the new third generation ICD flow mechanism, the multi-tasking valve (MTV) and a built-in sliding sleeve. The new third generation ICD flow mechanism is a labyrinth flow path design that is strongly dependent on the fluid density (the lower the density, the lower the pressure drop across the ICD), therefore making the ICD viscosity insensitive to fluids; the ICD is virtually insensitive to viscosities up to 300 cp. Another advantage of the new ICD design is the adjustability of the flow resistance rating (FRR) feature that provides reservoir engineers further option in designing the lower completion. The new ICD design also features the MTV valves, which simplify the deployment of the completion therefore making the deployment operation safer and more cost-effective.
Prediction of Residual Cement in Drillpipe after Balanced-Plug Job Using Finite Difference 3D Displacement Simulator
Authors: Edwards Joseph H. , Fuller George A. , Palla Venkata Gopala , Yerubandi Krishna Babu , Savery Mark 
Published: October 2013

Abstract
Drillpipe (DP) work strings are used for continuous operations during the drilling phase and also for various cementing operations, such as running casing, liners, casing with inner string, squeeze jobs, and balanced-plug cementing. There are reported cases of residual cement adhering to the inside walls of the drillstrings after the cementing operation is completed, and the work string is pulled out of the hole (POOH). The residual cement ultimately hardens, and this hardened scale cracks and flakes off in various sizes because of vibrations and pipe flexing. There is a possibility that the larger sizes of scale may catch in the bottomhole assembly (BHA), plugging the measuring while drilling (MWD) tools, downhole motor, and even the bit. Cement scale may also plug work strings used in cementing plug and squeeze operations. In offshore deepwater operations, pulling out a plugged BHA or work string could cost USD millions in lost time, depending on the depth of the wellbore. During primary cementing, where the DP is used to run the casing, the cement scale from the reused DP could plug the float equipment, which may cause the premature release of the wiper plugs, packoff at tight restriction, or affect the hanger setting tools and may result in a major job failure.
A primary cause for residual cement on the inside of DP is zero velocity at the wall-fluid interface caused by a no-slip condition. A 3D displacement simulator was used to perform post-job analysis for two balanced-plug jobs on a deepwater Gulf of Mexico (GOM) well to predict the residual cement. The simulator solves momentum conservation equations for the velocity field, and a convective-diffusion equation for the concentration field. The deepwater GOM well had a work string consisting of a tapered string of 6.625-in. DP (0 to 10,500 ft) followed by 5-in. DP (10,500 to 23,800 ft) and 3.5-in. DP (23,800 to 24,800 ft). The selection, provision, and proper preparation of the DPs is solely the responsibility of the operator. The effects of wiper darts and fluid volumes on the thickness of the residual cement layer were also simulated. This type of 3D displacement simulator can be extremely valuable as a prejob cementing design tool and for post-job analyses.