bluuebunny/crossref_metadata_2025_split huggingface dataset:
DEO Application: Case Study on Delivering Top Quartile Performance in PDO
Authors: Al Hamhami Saif , Al Sheriyani Zayid , Al Adawi Anwar , Al Aghbari Mohammed 
Published: October 2013

Abstract
Field X is an exploration/ appraisal gas field located in North Oman. Four wells had been drilled up to mid 2012 where drilling performance was poor. A promising gas discovery in the fourth well drove a decision to accelerate the delivery of another four wells in a short period of time in order to further appraise the prospect and hence accelerate field development.
The time constraint for planning another four wells and the poor drilling performance experienced in the first four wells called for a step change in the approach of planning and execution of these wells. A dedicated team was formed to plan the wells applying DEO concepts.
The DEO approach looked at offset wells and nearby fields' practices with detailed time breakdown, taking best practices for replication and addressing risks/ pain areas to remove performance limiters. It then looked at new technologies available in the market that can be implemented to overcome or eliminate performance limiters. Such new technologies implemented included casing drilling, inhibited drilling fluids, bits and BHA's.
The approach also looked at the different strategies for casing setting depths combined with mud programs and bits & BHA programs.
Detailed BHA modeling and analysis was conducted to choose optimum bits/BHA combinations with optimum parameters per formation.
A direct and continuous communication and engagement with the execution teams, office and rig teams, was maintained throughout the planning, execution and post drilling. This was one of the key success factors in implementing the improvements.
The results were stunning by delivering those wells in an average time half that of the first four wells, bringing significant cost savings and making the project economics for the field development even more attractive.
This paper will explain the DEO methods implemented that enabled the top quartile performance in these wells and share lessons learned from such implementation.
First Installation of 16-in. Solid Expandable Liner Solves Shallow Drilling Problems; Opens New Doors for Hole Size Preservation
Authors: Shaikh Ali , Duran Roberto C. , Abouelnaaj Khaled Khater , Fritsch Jerry , Andrews Stacey , Baker Roy 
Published: October 2013

ABSTRACT
In April 2012, the world's first 16-in. solid expandable tubular (SET) liner was run to depth and successfully cemented and expanded. The installation of the large diameter liner marks a significant shift in the application of expandables from deeper contingency applications to planned hole-conservation designs in the upper wellbore.
The purpose of the installation was zonal isolation. In Saudi Arabia, the Uthmaniyah field, the prolific Arab D reservoir has been produced for many years, resulting in lower pore pressures than the shallower Arab A, B, and C reservoirs. Due to the differences in pore pressure, isolation between the Arab D and Arab A, B, C reservoirs is required to efficiently drill some of these wells.
The 16 × 18-5/8-in., 115 lb/ft open hole liner (OHL) system isolated the Arab D reservoir by covering the Arab A, B, and C reservoirs while minimizing the loss of hole diameter to maintain the original wellbore design and drilling tools. Both objectives were safely and successfully achieved with the running and expansion of 1,708 ft (pre-expanded length) of 16-in. solid expandable pipe, hung as a liner and anchored into the 18-5/8-in. casing.
To isolate the pressure differential, the 16-in. SET liner was installed in a negative pressure environment. Once the liner was installed, the mud weight was reduced to drill the lower pressure Arab D reservoir and the remainder of the hole section. From a reservoir management viewpoint, this installation eliminated cross flow from the higher pressure Arab A, B, and C into the Arab D reservoir, thus preserving the pressure regime of the oil producing Arab D.
Additional benefits of the 16-in. expandable liner included an increase in ROP in the hard rock environment, the elimination of two-stage cementing requirements and the associated risk of stage tool failure, and reduction of hook load requirements associated with large, long casing strings.
Fully Mechanical 3-D Rotary Steerable Tool Brings RSS Performance to the High-Volume Drilling Market at a Fraction of the Cost to Conventional Rotary Steerable Tools
Authors: Hershberger K. , Herrington D. 
Published: October 2013

Abstract
The high-volume, land-based drilling markets have become increasingly demanding over recent years. Drilling complex, extended-reach horizontal wellbores through multiple targets with tighter windows is becoming increasingly common. Rotary Steerable System (RSS) technology, originally designed for the offshore drilling market, has proven to be an effective solution to the increasingly difficult challenges in the land-based market, but the cost of these high-end systems are simply not sustainable for many operators in the high-volume markets.
While RSS technology has clear performance-added value, adaptation into low-cost applications has been limited. High operating costs, damage charges, and extremely high Lost-In-Hole (LIH) rates have made it difficult for operators to justify their use, as the benefits simply do not justify the financial risks. Additionally, the harsh drilling environments found in many land applications lead to premature failures of the electronic components of the RSS, which can cause the tool to steer out-of-control, leading to expensive downtime. The high-volume drilling market requires a robust RSS capable of withstanding harsh drilling environments while delivering the proven RSS advantages at a price that is economically viable.
A 100% fully mechanical rotary steerable tool has been developed specifically for the high-volume drilling market, providing full 3D directional control while under full rotation of the drillstring from surface. This rugged and durable push-the-bit RSS has eliminated the costly and sensitive electronics common to most RSS tools and a number of vibration-related failure modes, making it suited for applications where shock and vibration are prevalent and high temperature applications. Utilizing engineered stabilization and proven 3-point geometry to keep the wellbore on target, this tool produces a premium wellbore with an increased Rate of Penetration (ROP) and reduced tortuosity, all at a cost well below that of conventional RSS tools.
This paper provides field data from North American land operations, which show this fully mechanical RSS has produced ROP increases of over 75% compared to laterals drilled with steerable motors. This RSS tool has consistently shown ROP improvements not only in North America but from around the world, all while reducing operating costs and financial risks of LIH by as much as 40% compared to conventional RSS technology.
External Casing Patch: A New Approach To Recomplete The Gas Wells With Cemented Completions
Authors: Romero Javier A , Al-Jadeedi Faiza , Tucker Dennis 
Published: October 2013

Abstract
In search of increasing gas production in the Sultanate of Oman, PDO's well engineers face challenges during the exploration of unconventional gas reservoirs. The cost-effective development of those deep tight gas reservoirs requires high fraccing pressure and special completion designs. In the last few years, the procedure to address those challenges ended up being completion failures that occurred during and after high pressure frac jobs, forcing operational teams to shut down several highpotential wells for long periods of time. Those inactive gas wells are awaiting effective, remedial solutions or, on the other hand, be recompleted. However, the cemented-completion type of well design implemented by PDO since mid-late 2000's and widely used in most deep gas wells reduces the options to the minimum due to inability to replace existing 4½"x5½" completions. The fit-for-purpose technique selected to minimize the operational and financial impact of having high-risk, unusable gas wells was a ‘external casing patch’. Such initiative opened a window of opportunities to recover the desired gas production and to continue with planned development phase of the field without jeopardizing the integrity of those wells and the surrounded facilities. The implementation and subsequent optimization of this well-known technology will ensure reliability of the further cemented-completion operations and accountability of gas reserves.
A New Integrated Drilling and Fracturing Solution for Tight Oil Exploration: A Case Study from Central China
Authors: Yu Jian , Yan Rong Hui , Ye Xin Qun , Nie Xiang Bin , Wang Da Hai , Liu Pei Wu , Luo Yin , Wang Kai Hong 
Published: October 2013

Abstract
A pilot project was initiated by PetroChina-Changqing to test a new integrated drilling and fracturing solution for a tight oil reservoir in central China. The results indicated this new integrated solution is an effective way to access the tight oil with high production, even with permeability less than 0.2 md. The integrated solution included a horizontal well drilled with real-time image and near-bit measurements for accurate and timely well placement decisions, well placement technology for trajectory optimization, multistage fracturing technology to stimulate the tight reservoir, and a properly placed trajectory and updated geologic model to optimize the fracture design.
With good cooperation between the service company and the operator, this pilot project showed favorable production results. Production testing on the first horizontal well showed initial production of 120 m3/day in contrast to the vertical well production of less than 1 m3/day. The real-time image clearly indicated the trajectory position in the sand and provided confirmed information for accurate trajectory adjustment. Well placement technology was successfully applied in the tight oil reservoir, with net-to-gross KPI of 100%, and the well trajectory placement met the specific exploration purpose. A 14-stage fracturing job was successfully executed, with 65% of the fluid volume flowback.
Microseismic monitoring indicated that all of the intended reservoir was stimulated. The pilot project showed that the integrated drilling and fracturing solution using horizontal well technology was effective for a tight oil reservoir. This solution can be applied to other tight oil blocks to improve tight oil exploration and development.
Real Time Determination of the Instability in the Borehole by Using 4D Images of the Wellbore with High Accuracy Ultrasonic Caliper
Authors: Elahifar Behzad , Esmaeili Abdolali , Thonhauser Gerhard 
Published: October 2013

Abstract
An ultrasonic sensor has been developed for MWD (measurement while drilling) and LWD (logging while drilling) applications that perform real time borehole caliper measurements and also wellbore stability monitoring. The caliper determines the oval shape of the borehole with a defined accuracy and resolution, and will allow drawing conclusions on the stress field.
Recognition of variations in borehole shape in real time drilling allow the drilling engineer to actuate appropriate counteractions to avoid costly failures, or to implement alterations in the drilling practices to optimize the shape of the borehole and thus improve the drilling efficiency. The received data helps the driller to make proper decisions such as reaming a critical zone, changing the flow rate to reduce erosion or modifying the string rotation speed to reduce vibrations. This paper reviews tests and experiments, which have been performed using two different ultrasonic sensors in different drilling fluids and also different wellbore conditions. The comparison of the results of high frequency and low frequency sensor will help to design and manufacture an ultrasonic caliper which can detect instabilities in the wellbore with high resolution recorded data. Effects of drilled cuttings and gas bubbles on both sensors are analyzed and the attenuation and scattering of the signals were reduces by the new design of the caliper. In the new design of the ultrasonic caliper, sound velocity could be determined in real time at the pressure and temperature of the downhole condition. This will increases the accuracy of the measured diameter and the shape of the borehole in real time application.
Finally, even with the modern technology improvements, ultrasonic caliper cannot provide absolute accurate information for all drilling environments and conditions. Several operational factors such as mud density, borehole wall roughness and tool position in the borehole among others need to be considered in order to optimize the accuracy of the borehole caliper data. For this reason analysis of circle fitting algorithms based on the Kasa method have been implemented. Using this method and the new design of the caliper tool, accuracy of the recorded data increases.
Pioneer Step in Securing Gas Well with Through Tubing Retrievable Bridge Plug Under Highly Complex Circumstance (1st Time in the Middle East)
Authors: Negm Asaad M. , Al Kholy Ahmed B. , Al Mutawa Ahmed Abdulla , ElBarbary Abdalla Youssef , Al-Hosani Mohamed Salem , Salim Bassam 
Published: October 2013

Abstract
During a tubing depressurizing operation in a sour gas producer, the Sub-Surface Safety Valve dislodged from the nipple profile, broke and stuck inside the tubing hanger, restricting accessibility to the well. Multiple attempts to recover the stuck fish via slick line in combination with a permanent magnet resulted in recovering a few broken pieces and revealed a limited clearance of 1.85" through the fish.
The well was killed and attempts to secure the well by installing through tubing inflatable bridge plugs using coil tubing were unsuccessful. It was then decided to exclude the coiled tubing operation for well integrity purposes due to limited clearance as the coil tubing had to pass through broken fish and could get stuck compromising the X-tree valves operation and it was decided to carry out work over operation to recover the broken fish. The cost for well work over was estimated at $ 3.0 MM.
An innovative approach to secure this gas well riglessly using through Inflatable bridge plugs setting with electric line was introduced and the job was conducted successfully after completing all the risk assessments saving the significant costs associated with rig intervention. Two 1-11/16" through tubing inflatable retrievable bridge plugs (TTIRBP) were set with electric line passing thru the limited access hole of the broken fish. Plugs were set inside 4-1/2" and 3-1/2" tubing and pressure tested to 3000 PSI.
The well was secured and the fish was successfully retrieved. Both bridge plugs were retrieved using 0.108 inches slickline and the well was put back into production.
This great achievement was recognized as a 1st trial to carry out securing a sour gas well in the Middle East using a combination of electric line and slick line for setting and retrieving TTRPB
Inflatable packers and plugs run on coiled tubing and wireline through production tubing for water & gas shut-off applications were introduced in late 1980s. This has brought substantial cost savings by eliminating the workover rig and all ancillary operations required by conventional workover in additional to bringing wells back to production in significantly less time.
Expanding the use of thru-tubing retrievable beyond their usual scope, to secure wells where maintenance work was required on x-mas trees, tubing hangers and in this example to retrieve and replace the sub surface safety valve stuck in the tubing hanger in a rigless environment sheds light on a whole new range of applications. The rigless program designed and executed successfully to secure the sour gas well utilizing through tubing retrievable bridge plugs.
CO2 Emission Reduction Through Power Savings
Authors: Al Dakheel Sulaiman , Al dulaimi Raed 
Published: October 2013

Abstract
This study was conducted in Kuwait Oil Company (KOC) in an effort to reduce electrical losses from electromagnetic ballasts used for fluorescent lighting, reduce CO2 emission contributions, and decrease annual replacement cycles; a thorough survey was conducted in all South and East Kuwait (SEK) Directorate facilities to determine the type of ballasts being utilized to compute the losses resulting from the use of electromagnetic ballasts. Comparing the losses in electromagnetic ballasts and electronic ballasts using the CELMA (Federation of National Manufacturers Associations For Luminaires and electromechanical components for Luminaires in the European Union) standards, we were able to conclude that losses up to 1,398,412 kwh per year or aproximatly 25%, and at 830g emitted for the utilization of 1 kwh in Kuwait, emissions reductions up to 1,162 Tonnes of CO2 or aproximatly 25% can be achieved through a direct replacement of all electromagnetic ballasts with electronic ballasts. Furthermore, replacement cycles were also reduced due to a 40% increase in average life, which would reduce the operating cost by 45% over 50,000 operating hours. Hence, the utilization of electronic ballasts is more efficient, environmentally friendly, and cost effective than using the electromagnetic ballasts.
Real Time Data Transmission Method for Creating 4D Wellbore Images to Detect Instabilities with High Accuracy Ultrasonic Caliper
Authors: Elahifar Behzad , Esmaeili Abdolali , Thonhauser Gerhard 
Published: October 2013

Abstract
3D images of a wellbore generated in real time support drilling engineers to monitor wellbore profiles. Including the time as 4th dimension, 4D images can be used to analyze the evolution of the wellbore geometry as well as to support the drilling engineer in actuating appropriate counteractions in real time. Costly failures can be avoided more precise, alterations in the drilling practices to optimize the shape of the borehole will improve the drilling efficiency, or the driller is supported in making proper decisions such as reaming a critical zone or modifying the string rotation speed to reduce vibrations.
This paper reviews tests and experiments, which have been performed using high frequency ultrasonic caliper sensors in different drilling fluids and wellbore conditions. Test results show that with the new design of an ultrasonic caliper tool velocity of sound can be determined in real time at the pressure and temperature of downhole condition. This will increase the accuracy of the measured diameter and the shape of the borehole in real time.
In addition, a method for fast data transmission from down-hole to surface is presented and the best method for transmitting data to create the 4D images is discussed.
Even with such technology improvements the ultrasonic caliper cannot provide absolutely accurate information for all drilling environments and conditions. Several operational factors, such as mud density, borehole wall roughness, and tool position in the borehole need to be considered in order to optimize the accuracy of the borehole caliper data. For this reason, robust circle fitting algorithms based on the Kasa method have been implemented. In combination with the new design of the caliper tool, the accuracy of the results has been strongly increased.
3D Near Well Structural Modeling from LWD Imaging Logs Using Recent Advanced Interpretation Platforms
Authors: Bahadidah Taleb A. , Khan Fahad Q. , Dashti Rouhollah , Mustapha Muhd Syaiful 
Published: October 2013

Abstract
In one of the biggest discoveries during last 10 years in South East Asia, two recent highly deviated wells with length of over 3000 m were drilled in order to enhance the understanding of the reservoirs properties and characterization (Figure 1). Logging while drilling (LWD) images were acquired, processed and interpreted. This was performed subsequent to the very first successful and largest multiwell geological reservoir characterization performed for this operator in South East Asia. After doing the conventional borehole dip and structural analysis for both wells, a unique integration approach has been implemented for both wells using some recent advanced interpretation platform in order to create 3D near well structural model. This model has been updated with formation tops. Several steps and workflow has been implemented and finally local update of static model has been performed. The resulted structure axis has been calibrated later with seismic based map showing a structural axis direction towards NE-SW which is matched with the seismic derived structure map. Figure 1Location structural map of the entire field of the studied wells.
Considerations for Design of Steam Reforming Hydrogen Plants
Authors: Overwater Koos , Ratan Sanjiv , Sekhri Sanjeev , van Uffelen Roland 
Published: October 2013

Abstract
This paper will address the major considerations for the design of hydrogen plants based on the steam reforming process, which is the most commonly applied technology for hydrogen generation.
In refineries hydrogen is an essential utility to prepare clean transportation fuels. It is not only used for hydro treatment of finished products, but also for deeper hydro conversion of heavier and sourer crude fractions, for instance in hydrocrackers.
In most refineries a hydrogen plant is present that feds into a network that serves the various consumers. Often recovered hydrogen from off gas streams from hydro processing units or catalytic reformers is (re-)injected in the network.
Steam reforming is an endothermic process where hydrogen is generated by reaction of steam with hydrocarbons over a Ni-based catalyst. Usually the reactor is a direct fired multi-tube reactor, operating at temperatures around 850 - 920 0C, and pressures around 25-35 barg. Due to the high reaction temperatures, the heat recovery from flue gases and process gas is an essential part of the design of the hydrogen plant, and determines largely the overall efficiency of the plant.
Following topics are addressed: –Plant flowsheet–Process design optimization–Feedstock flexibility–Hydrogen generation vs. hydrogen recovery–Furnace mechanical design (furnace types, design aspects of radiant and convection section, internals, supporting, piping manifolds, ducting, etc)–Furnace operations and safeguarding–Managing NOx emissions
Hydrogen production is an essential part of nowadays refinery set-ups. The design of the hydrogen plant shall be carefully optimized between technology licensor and end-user, as it is a large energy consumer, represents substantial investment cost and is deeply integrated into the refinery.