bluuebunny/crossref_metadata_2025_split huggingface dataset:
Deepwater Success Through Predictable and Distinctive Drilling and Completion Performance
Authors: Wardt John de 
Published: December 2007

Abstract
Benchmarked results on well construction projects show that many projects incurred significant cost over runs. Half of the mega projects since 1993 have been disasters resulting in a destruction of capital for oil companies. Insufficient drilling front-end loading and inadequate team organization have been identified as preventable causes of these over runs.
Deepwater projects involve multiple challenges of new technology, geological uncertainty and, often, a fast track approach. The wells' portion of the total project cost often exceeds 50%. The huge price for intervention activities later in the life of these wells requires that the initial completion remain in place and function as planned for a long time.
Predictable and distinctive drilling and completion performance is a must for the high cost projects that typify deepwater.
This paper will describe a methodology that has been successfully applied with repeatable best in class results in the North Sea and Gulf of Mexico. This methodology addresses the need that teams are organized to fit the project (not the other way around) and that systems integration is treated as a high priority. The results typically achieved with this methodology are in the range 20 – 23 days per 10,000 ft – best in class in both regions and 35% better than the average drilling time – with commensurate improvements in production and data acquisition. Short case histories of deepwater exploration and development wells are described – including a horizontal development well.
The paper describes:
– how the projects were organized, – how the teams were aligned to their objective and goals, – the processes that support these successful teams, – how the teams were motivated to perform, – how web based support can function to create co-location through the virtual world.
The paper also contrasts this methodology with traditional operations.
Beyond the Best Initiatives Deliver Breakthrough Performance: Deep Exploration Well, Colombia
Authors: Frazelle Andrew , Sarmiento Juan Francisco , Vargas Reynaldo , Garoby Juan , Krasuk Raul 
Published: December 2007

Abstract
Drilling the structurally complex overthrusted fault blocks associated with the Andes foothills of Colombia has always presented a number of distinctive challenges. Borehole instability, hard and abrasive formations, undesirable hole deviation associated with multiple fault planes and steeply dipping formations, low progress rates and frequent drill string failures are the most common problems encountered while drilling wells in the area.
In order to efficiently drill a deep exploration well in Colombia, the operator elected to implement its internal Beyond the Best (BtB) initiative to increase the chances of achieving or exceeding performance goals. A strategy was developed to anticipate challenges and address critical elements of the detailed design, the identification of the optimum well trajectory to manage subsurface hazards as well as continuous updates of the subsurface model while drilling. As a part of the Front End Loading requirements of the BtB initiative, the operator elected to engage a drilling optimization service to conduct a detailed analysis of the overburden including a critical review of drilling performance, mud logging and wireline data from reference wells. This detailed and in-depth analysis helped identify potential problems that led the operator to set optimization objectives for the upper hole sections of achieving the highest penetration rate possible while maintaining a near-vertical wellbore. An action plan with recommended solutions to overcome anticipated problems was developed and specific fit-for-purpose technologies were identified as appropriate solutions.
To introduce and build support for this new drilling philosophy and tool implementation, the operator implemented the Technical Limits Process that challenged operator and service company personnel to work as an integrated team to achieve best-in-class drilling performance using the appropriate technology. The process also encourages trust and camaraderie between team members and challenges them to feel personally responsible for delivering significant performance improvement. The authors will discuss how proper planning and understanding key issues that previously restricted drilling performance led to the identification of improved drilling practices and the application of the proper technology that resulted in breakthrough drilling performance including new world records for impregnated and PDC bits.
To measure the effectiveness of the initiatives, the authors will document savings relative to offset wells. The typical well drilled in the Colombian foothills averages 188 days per 10,000 feet to complete. However, by applying application specific technology the team has cut the average time required to drill this well to 140 days per 10,000 feet with the resultant savings in time and money to the company.
Successful Horizontal Drilling in Western Siberia: Use of Appropriate, Cost-Effective Technology Solutions to Increase Well Productivity
Authors: Diyashev Iskander , Lishchuk Vasiliy Yurivich , Aker Gokhan , Bustos Oswaldo , Prakash Leslie 
Published: December 2007

Abstract
The introduction of Western horizontal drilling techniques into Siberia has achieved outstanding results for Sibneft, a Russian independent operator. Before 2000, vertical or directional S-shape wells were being drilled to develop the Sibneft-NoyabrskNeftegaz oil fields using local techniques provided by Siberian drilling contractors. An alliance with a major Western service provider made possible a Western-Russian design group familiar with all available options. The group created an ideal marriage of Western and Russian fit-for-purpose equipment, procedures, and techniques for a cost-efficient horizontal well design.
The methodology applied in this project is a fusion of classic Russian drilling techniques, i.e., compact rigs skidding on a rail system with aluminum drillpipe with Russian turbines to drill tophole sections, coupled with modern horizontal technology such as steerable motors and mud pulse telemetry measurement-while-drilling (MWD) and logging-while-drilling (LWD) systems. To date, 90 wells have been drilled with a progressive learning curve enabling wells to be drilled to around 4000 m (with more than 1000 m of horizontal section) in less than 48 days that at the start of the campaign were taking more than 100 days.
The successful integration of these cost-effective solutions has been pivotal in helping Sibneft approach its production targets. Today the 90 wells drilled in the last 3 years (out of 4,500 total wells) account for approximately 175,000 BOPD, or one quarter of total Sibneft production. The cooperation of reservoir and drilling engineering teams from the service provider and the operator was critical to project accomplishments.
Novel Drilling Fluid for Through-Tubing Rotary Drilling
Authors: Franks Todd , Marshall David S. 
Published: December 2007

Abstract
Through-Tubing Rotary Drilling (TTRD) is a technique which has been developed to extend the production life of older fields by substantially reducing drilling costs to render smaller reserves of oil economically recoverable1. However, the small wellbore dimensions required to utilise drill-pipe inside production tubing place some unusual demands on the drilling fluid and when these are compounded by the challenges of drilling into a formation containing a large range of pressures in the reservoir and high pressure shales, a radical approach to drilling fluid design is required.
The requirement for a low viscosity fluid (to minimise ECD) which would still meet all other drilling requirements meant that conventional fluids were all unsuitable and a review of the options available resulted in the selection of a novel weighting material, manganese tetraoxide, for use in a mineral oil-based mud as the system most likely to provide the desired properties. The physical properties of commercially available manganese tetraoxide (very small, spherical particles) were known to result in very low plastic viscosities in muds made with this material when compared to muds weighted with barium sulphate. A much-reduced potential for weight material sag was an added bonus.
This paper details the design considerations of the fluid used to drill three TTRD side-track wells in Shell's North Cormorant field. Modelling of hydraulic parameters is presented, together with field results from the first well and how these led to modifications of fluid design and engineering practice which were incorporated into the subsequent wells.
Drilling Fluids for Wellbore Strengthening
Authors: Aston M. S. , Alberty M. W. , McLean M. R. , de Jong H. J. , Armagost K. 
Published: December 2007

Abstract
There is a clear advantage to drilling if we could strengthen the wellbore and drill at higher mud weights without losing fluid. A major prize is accessing difficult reserves in depleted reservoirs. Another application is in deep water drilling where the drilling window between pore pressure and fracture gradient is often narrow. This paper describes the approach taken by BP to produce a ‘designer mud’ which effectively increases fracture resistance whilst drilling, and which can be applied in both shale and sandstone. It works by forming a stress cage using particle bridging and an ultra-low fluid loss mud system. The theory is described and laboratory data show how the fluid system was developed. Field data are shown which quantify the increase in fracture resistance and demonstrate the value of the system. Logistics issues are discussed.
Reservoir Navigation Tool Successfully Used in a Unique Way to Determine Relative Orientation of Dual 13 3/8 in. Casing Strings in a Shared Conductor Well
Authors: Foekema Nico , Oden Ezimah , Jones Brendon 
Published: December 2007

Abstract
This SPE Paper describes the way that the relative orientation of two 13 3/8" casings, run in a single 32" hole, was established using azimuthal gamma sensors from a reservoir navigation tool and several radioactive PIP tags mounted in one of the casing strings. The technique uses standard oilfield equipment and has proven easy to perform. Several SPE papers have been written explaining the use of magnetic or acoustic sensors for orientation purposes, those techniques could have been used but would have been cumbersome and more expensive to use.
Improving Drilling Performance Through Systematic Analysis of Historical Data: Case Study of a Canadian Field
Authors: Adeleye A. R. , Virginillo B. K. , Iyoho A. W. , Parenteau K. , Licis Henry 
Published: December 2007

Abstract
Drilling operations daily generate large amounts of data but surprisingly, a significant proportion of these data are not utilized in a manner that shortens the learning curve and promotes drilling efficiency. The authors, through this paper, demonstrate how drilling analysis methodology helped identify performance gaps in a West Central Canadian field.
The above is captured under the much espoused philosophy characterized by the questions:
Where are we now? What is possible? How do we get there?
By applying this tool, significant cost savings to the tune of CAD$7.3 mln have been achieved as at the time of preparing this paper.
An Innovative Design Approach To Reduce Drill String Fatigue
Authors: Hill Tom , Ellis Sean , Lee Kang , Reynolds Nicholas , Zheng Nanjiu 
Published: December 2007

Abstract
Fatigue and corrosion fatigue account for the majority of drill string failures.1,2 The complexity of fatigue and the drill string designer's inability to account for a great many factors affecting the mechanism make it impractical or impossible to accurately predict a component's fatigue life in cycles to failure. This paper describes the comparative design approach. This new approach normalizes many factors affecting fatigue that are generally unknown to the designer, allowing him or her to quantitatively compare the fatigue performance of available alternatives on the basis of what he or she does know. The method has already proven effective in field use.
Effective Sand-Control Completions in a Remote Development—Chad, Africa
Authors: Witteveld Andreas D. , Cutright Derek , Hayes Joseph E. , Ellis Richard C. 
Published: December 2007

Abstract
Chad Development Project consists of three fields (Kome, Miandoum, and Bolobo) in the Doba basin. Completions in the Upper Cretaceous reservoirs must address the following characteristics:
Unconsolidated permeable sands (0.5 &lt; k &gt; 20 Darcies). Large average particle sizes (100 to 1,000 microns). Broad particle size distributions (uniformity coefficient— d10/d50—ranging from 3 to 8+). Sand layers separated by highly reactive shale. Low-gravity, high-viscosity crude oil (30 cp to 400+ cp). Separate oil/water contacts for different sand intervals. Completion interval lengths spanning a few tens of feet for a single sand to several hundred feet commingling several sands.
It is a challenge to design an efficient and reliable sand-control completion for these characteristics. Individual sand-control completion designs were evaluated by a multidisciplinary completion team (geology, reservoir, completion, and production engineers). To date, five types of sand-control completions have been used in the Chad project: high-rate water packs (HRWPs), frac packs (FPs), frac packs using shunt tubes (FPw/Shunts), FPw/Shunts and an isolation Packer (FPw/shunts&IP), and openhole stand-alone screens (OH-SAS). Only cased hole completions are addressed in this paper.
When this paper was prepared, 51 sand-control completions had been installed in Miandoum field. Initial postcompletion well performance was measured using short duration (24- to 48-hr) cleanup and test periods.
A significant learning curve for completion quality and operational efficiencies was overcome by both operations and engineering teams working together closely to improve techniques.
This paper will describe the technical and operational hurdles as well as the results achieved with various completion methods.
Technological Advances in Completion Pipe Design
Authors: Christen Brian L. , Jellison Michael J. , Tinker Steven J. , Walker Tim , Broussard Steve 
Published: December 2007

Abstract
New design challenges for deepwater, extended-reach and other critical completion operations have limited the use of conventional industry standard workstrings and prompted development of a new Completion Pipe capable of addressing demands for high torsional strength, gas-tight seals and a streamline connection profile.
Tubing configured with premium connections has traditionally been used to perform high-pressure completion operations. As water depths, well depths, and well angles have increased, so have the performance demands for the pipe. Torsional capabilities of premium tubing strings are often limited in these applications. Completion pipe provides the torsional strength and robustness of a high performance tool joint connection with the pressure integrity of a premium metal-to-metal gas tight seal connection.
Innovations in high-performance tubular design as well as step change improvements to existing connector technologies has led to the development of a specialized drill pipe tubular with metal-to-metal pressure seal connections as a new completion pipe option. Maximizing tool joint inside diameter and shifting tube upsets to the exterior are options for minimizing flow restrictions. The dimensional flexibility of these durable, streamlined high performance tool joints provides advantages not seen in typical API tool joints or threaded upset tubing connection configurations. Flexible connection configurations and optimized tubular design satisfy standard completion tubular profiles as well as very specific fit for purpose applications.
The paper offers solutions to completion engineers involved in planning and executing critical completion operations in deepwater, extended reach and ultra-deep wells. This paper presents key tubular design considerations for meeting torsion, tension, hydraulic, pressure integrity and pipe recovery method requirements of critical completion operations. Mechanical characteristics of assemblies and field performance of application specific completion assemblies are presented.
Wellbore Cleanup by Water Jetting and Specific Enzyme Treatments in Multilateral Wells: A Case Study
Authors: Al-Otaibi M. B. , Nasr-El-Din H. A. , Siddiqui M. A. 
Published: December 2007

Abstract
Many horizontal and multi-lateral wells are drilled using water-based mud in Saudi Aramco fields. Generally, the drilling fluid consists of xanthan, starch or cellulose polymers with bridging agents like sized calcium carbonate or salt particles. During drilling and completion operations it is essential to form a filter cake to control fluid losses. However, inefficient cleanup of the filter cake may lead to significant losses in well performance. Water jetting techniques and specific enzyme treatments were recently introduced in Saudi Aramco to cleanup the filter cake following drilling operations.
In multi-lateral wells in carbonate formations, the external filter cake is typically cleaned by enzyme treatments in laterals without fluid losses, whereas high-pressure water jetting is used in wells with some fluid losses. This strategy was recently applied in a tri-lateral well drilled in a carbonate reservoir. The bottom hole temperatures for the main, first and second laterals are 183, 169 and 171°F, respectively. Also, the length of the target zone for the main bore, and the two laterals ranges from 3,000 to 7,000 ft. The reservoir pressure is 2,400 – 2,500 psi.
Field data indicates that utilization of enzyme treatments and water jetting are very effective techniques in removing drilling mud filter cake. Fluid losses significantly increased during cleanup of filter cake by water jetting. Oil production reached the target value without the need to acidize the treated well. Flowback samples were collected and the nature of solids produced and their particle size distribution were measured. This paper presents various aspects of water jetting, field data and lab results based on the analysis of well flowback samples.
Issues and Solutions for Cementing Expandable Liners: A Case History
Authors: Rahman Rashid Abdul , Zulkafly Ahmad Humaizy 
Published: December 2007

Abstract
The oil and gas industry has in general already in place an established set of good cementing practices to meet the overall objectives of cementing. These practices have been refined and perfected over decades of industry experience in the discipline. However, new technology of expandable liners brought about its own set of cementing issues and requirements based on the equipment design constraints. Some of the requirements run counter to the established good cementing practices. This paper discusses some of the new cementing issues and requirements for expandable liners and their implications on the overall effectiveness of the cement job. Optimizing the cement job involves addressing the issues and taking a compromise between the new cementing requirements and the established good cementing practices. This paper discusses some of the available solutions for the cement job optimization with a view to meet the overall cementing objectives. Finally, a case history where the above has been successfully implemented is presented and discussed.
Increasing Effective Fracture Gradients by Managing Wellbore Temperatures
Authors: Gonzalez Manuel Eduardo , Bloys James Benjamin , Lofton John E. , Pepin Gregory Paul , Schmidt Joseph H. , Naquin Carey John , Ellis Scot Thomas , Laursen Patrick E. 
Published: December 2007

Abstract
Thermal effects on wellbore stresses can have a significant impact on effective fracture gradients. Changes in wellbore temperatures caused by various drilling operations provide for these thermal effects. For example, circulation on bottom usually results in lower bottom hole temperatures than the static geothermal temperature. This cooling effect reduces the wellbore stresses resulting in lower effective fracture gradients. Minimizing the cooling effect by increasing wellbore temperatures can increase effective fracture gradients and the corresponding pore pressure/fracture gradient margin avoiding costly lost circulation and additional unnecessary casing points.
This paper presents results from leak-off tests taken at various temperatures which demonstrate the thermal effect on formation stress. This paper also examines the effects of operational factors on wellbore temperatures to minimize the cooling effect and/or increase effective fracture gradients. Software developed for thermal simulation of various drilling operations was used to perform the analysis.
Use of Reliability Centered Maintenance (RCM) Analysis in Petroleum Development Oman (PDO) for Maintenance Rationalization
Authors: Khamis Busaidi , Hiren Sarma 
Published: December 2007

Abstract
Facing with the constant challenge for improved plant reliability at a lower cost, today's Asset Managers have been looking for various ways and means to rationalize their business activities. Being a major part of the business management system, maintenance discipline is also responding to this call. While the maintenance approach has gone through a series of evolutionary changes over the last 30 years, the managers are now looking for a more methodical and structured framework for analyzing and recommending the maintenance needs. Reliability Centered Maintenance (RCM), which takes a holistic approach encompassing integrity, health, safety, environment, financial, technology and human resources is designed to provide such a framework.
Since a large number of text books and publications are available on this subject, this article will mainly address PDO's experience in utilizing the RCM methodology through a project and some "Dos" and "Do Nots" based on the author's learning points. A brief background on the RCM methodology is provided for the readers who may not be familiar with the RCM process.
ESP Performance in Mubarraz Field
Authors: Miwa Masahiro , Yamada Yutaka , Kobayashi Osamu 
Published: December 2007

Abstract
Abu Dhabi Oil Co., Ltd.(ADOC) has been applying artificial lift with ESPs in Mubarraz Field, offshore Abu Dhabi, U.A.E., since 1975. In 1989, the authors published a paper which presented the trouble analysis, technical improvements and actual ESP Performance. Since then ADOC continued making efforts to increase the ESP Lifetime by applying technical improvements and countermeasure against ESP troubles. By this result, the average lifetime was increased from 2.1 years to 3 years. In particular, the longest lifetime reached is 3,617days, compared with the old record of 1,659days mentioned in the paper1).
Furthermore, detailed inspection of troubled ESPs and investigation on the new ESP units had been carried out. With intensive discussion between ADOC and the ESP manufacturer, the new ESP units were selected in 1995 and had been installed in the field.
This paper presents the technical improvement, countermeasures against the different ESP troubles including asphalten precipitation and corrosion protection, proper selection of new ESP units and actual performance of ESPs as a result of these improvements.