bluuebunny/crossref_metadata_2025_split huggingface dataset:
True Zonal Isolation in Openhole Alternate Path Gravel Pack Completions
Authors: Barry Michael D , Hecker Michael T. , Yeh Charles S. , Moffett Tracy J. 
Published: March 2012

Abstract
Openhole completions are often selected as the preferred completion technique to maximize reservoir flow potential and provide reliable, high capacity, low skin completions. With the advances of Alternate Path® Technology (APT), a full gravel pack can be realized under challenging well conditions to provide increased long-term reliability. One drawback to openhole gravel packs has always been the inability to isolate water or gas, whether it is during the initial completion or during the production lifecycle of the well. ExxonMobil embarked on a multi-year initiative to develop, qualify, and successfully deploy Shunt Zonal Isolation (SZI) packer technology that, when combined with Internal Shunt Alternate Path Technology (ISAPT) screens, can provide true zonal isolation in an openhole gravel pack completion.
The new openhole technology enables greater extended drilling to capture additional pay, selective completions to isolate zones, and production flow control inside the screen basepipe similar to cased hole conditions. True zonal isolation in openhole gravel pack completions facilitates more flexible well planning and operational execution while maintaining reliable sand control. This paper will explore the range of application opportunities this new technology presents.
A Systematic Approach to Improving Directional Drilling Tool Reliability in HPHT Horizontals in the Haynesville Shale
Authors: Pinto Errol , Mota José , Grable Jeffery , Ward David 
Published: March 2012

Abstract
Unconventional shale gas has become an increasingly important source of natural gas in the United States over the past decade, and interest has spread to shale-gas plays in multiple countries. Shale gas is expected to continue to supply larger shares of the natural-gas production in North America by 2020.
One of the most active shale plays in North America is the Haynesville, which represents extreme challenges in drilling horizontal lateral sections with 16,500–18,500-ft measured depth wells and flowing temperatures that can exceed 375°F at section TD. This paper examines a collaborative and systematic approach between the service provider and operator to drive relentless performance improvements in the production interval of the Haynesville.
In 2009, the team set out a challenge to eliminate mud motor and MWD failures in the production interval. The approach outlined in this paper will explore how root-cause failure analysis, new condition-based maintenance systems, and field-operation processes were used to systematically push MWD, mud motor, and LWD performance in this hostile environment.
Blowout Preventer (BOP) Health Monitoring
Authors: Mckay Jim , Simmons Clayton , Hogg Tony , Starling Gavin , Doty Mike , Pere Allen 
Published: March 2012

Abstract
As every motorist knows, a vehicle’s dashboard is an important interface that alerts the driver of real-time changes regarding certain car engine "health?? metrics and alerts the driver that the engine may need to be serviced. While not a diagnostic tool in and of itself, the dashboard serves to alert the driver that a performance or health issue may exist. Blowout Preventer (BOP) equipment is designed to secure the well and a BOP’s health is critical to ensuring that it works as designed. A realtime BOP dashboard can improve communication between operations personnel, rig contractor subsea engineers and the Original Equipment Manufacturer (OEM) to assess potential BOP health issues.
This paper describes a development process for a BOP dashboard and discusses the potential benefits, challenges, and lessons learned associated with implementing a BOP monitoring system.
Upgrading the Real-Time Drilling Optimization Culture in Brazil’s Challenging Deepwater Operations: The Utilization of a Remote and Rigsite Multidisciplinary Collaborative Concept
Authors: Borella Hougaz Augusto , Gozzi Danilo S. , Fujshima Isao , Vello Klaus L. , Alves Sandro , Thomson Ian , Krasuk Raul , Buzzerio Frank 
Published: March 2012

Abstract
In recent years deepwater drilling operations has become more challenging and expensive, new exploratory frontiers and the rise of rig rates demanding the need for first-class drilling optimization technology and services. In Brazil, deepwater well construction activities increased significantly since the first major pre-salt discovery in the Santos basin in 2006.
In this highly demanding and extremely challenging drilling scenario, building a drilling optimization culture based on the synergy and integration between a major deepwater operator and a leading service company has proven to be fundamental for achieving better drilling results and superior performance.
The creation of a multidisciplinary drilling optimization group, integrated with the operator’s drilling team in 2008, and the introduction of a highly specialized downhole drilling dynamics measure while drilling (MWD) tool changed the drilling optimization concept in Brazil. This new optimization concept pioneered the remote (off-the-rig) downhole drilling parameters surveillance in deepwater operations.
This paper will present the fundamentals of this real-time remote and rigsite drilling optimization concept, with focus on the integration between the operator and the service company, the operational aspects, with regards to appropriate communication protocols and decision-making processes, highlighting the performance improvement achieved to date.
Case Study on Bottom Hole Assembly Tool
Authors: Verhoef Richard 
Published: March 2012

Abstract
In these days of rig automation and advanced rig mechanization, the industry may wonder why running the Bottom Hole Assembly (BHA) still requires more people on the drill floor and more equipment then required when tripping in or out.
Part of the reason is that BHA’s are made up of many different components; each usually having a separate outside diameter, which means every component needs a specific set of hand slips. Furthermore, every component needs to be secured by a safety clamp to prevent unwanted pipe slippage. Both setting the slips and fixing the safety clamp is a manual process, which often requires 2-3 persons to complete. This is a potentially unsafe practice and it is imperative to find a reliable solution to meet this challenge.
The Bottom Hole Assembly Tool (BHAT) provides the solution to all of the main challenges faced when handling the BHA:
(1) many different diameters (2) safely running collarless components with relative low loads
The BHAT eliminates these problems because it is able to grip a wide range of diameters without component changes to the tool; it grips BHA components with the necessary force so the BHA cannot slip through and with such built-in safety features a safety clamp is not needed.
During the design and prototype testing of the BHAT, all individual design features have been examined in great detail; from the design of the inserts teeth profile, to the clamping force of the cylinders and its integrated safety features.
This paper presents the design challenges and the prototype testing leading to the final version of the BHAT.
Establishing an Industry Best Practice on Subsea Wellhead Fatigue Assessment
Authors: Buchmiller D. , Hørte T. , Grytøyr G. , Haug L. T. 
Published: March 2012

Abstract
Wellhead fatigue has received priority attention within the drilling industry, especially on the Norwegian Continental Shelf. Concern has also been raised in other areas of the world when drilling on existing older wells and when using new heavier rigs and BOP systems. Focus has been on developing a universal wellhead fatigue calculation methodology. This is part of an ongoing joint industry project (JIP) facilitated by DNV with participation from BG Group, BP, Chevron, Det Norske, Eni, ExxonMobil, GDF Suez, Lundin, Marathon, Nexen, Shell, Statoil, Talisman, Total and Woodside. Motivation for developing an industry guideline stems from the fact that existing international standards provide limited or no guidance on wellhead fatigue calculation.
A recommended practice is being finalized through the ongoing JIP, which builds on the strengths of the methodologies available in the industry today. The RP provides guidance on selection of methodologies for wellhead fatigue assessment based on the specific conditions for a subsea well.
Due to the harsh weather conditions and shallow waters of the North Sea, wellhead fatigue has historically been a challenge. There are uniquely different challenges in deeper water, such as the Gulf of Mexico, which influence the selection of the analysis approach. In recent years, there have been a number of papers published on wellhead fatigue, and the background for different methodologies as well as the key differences is presented in this paper.
It is crucial that the drilling industry is aware of the challenges with regard to a consistent safe design and operation of its equipment and that the industry is continuously pushing forward to improve upon design methodology and guidelines. This methodology incorporates key elements from the best practices from around world on wellhead fatigue analysis.
Regeneration of First-Generation Subsea Fields: The Challenges of New Wells in Old Infrastructure
Authors: Stright Sean , Srivastava Vikas , King Gregory , Smith David W. , Tears Nelson 
Published: March 2012

Abstract
A large number of subsea production wells have been drilled, but to date there has been limited industry experience of redrilling subsea wells, whereas, redrills have become routine in platform and surface wellhead applications. The focus of this paper is to highlight some of the key aspects of redrilling a subsea production well to extend field life.
The paper will describe how the unique challenges of redrilling three subsea wells were overcome in old and declining fields where the original wells were designed and drilled with limited consideration for redevelopment of the fields through reuse of existing wells. The paper will define the problems of and describe the solutions to:
The mooring and BOP handling constraints in the crowded subsea infrastructure of a subsea field development. The riser and wellhead analysis for redrilling a well through a subsea tree, and the operational practices required to maintain tree and wellbore integrity. The analysis of the additional loads put on a subsea well through the extended period of riser and BOP loading. The casing exit and redrill constraints unique to operations from a semi-submersible rig; casing recovery operations, the management of window milling debris in a subsea BOP system.
There has been limited industry experience to date of subsea production well redrills, and this paper will share the significant lessons learned which will be of wider application, as the number of subsea wells increase along with the requirement to maximize recovery and extend field life.
Size Degradation of Granular Lost Circulation Materials
Authors: Scott Paul D. , Beardmore David H. , Wade Zack D. , Evans Eddie , Franks Krista D. 
Published: March 2012

Abstract
Lost circulation is a major cause of drilling non-productive time with significant cost implications for many locations throughout the world. Increased attention on the performance of lost circulation materials and engineered solutions to lost circulation, such as wellbore strengthening and the recycling lost circulation materials, has brought about the need to use materials which do not size-degrade rapidly.
Little mechanical property data or shear degradation information is available for most lost circulation materials as they are normally not highly engineered materials, and standard test methods have not been developed. In addition, lost circulation materials are often sourced locally to reduce cost, and logistics are such that they may not come from sources with consistent quality.
Anecdotal information about which materials size-degrade most is common in the industry but little scientific information is available. Field data has conclusively shown that lost circulation materials degrade in size with time. A laboratory procedure has been developed and used to study the relative reduction in particle size of the most common granular products.
Laboratory and field data are presented to demonstrate the relative size degradation rates for several common lost circulation materials. This data on the relative degradation in the particle size distribution of granular lost circulation materials will provide improved understanding of their performance for more efficient application of the materials. This will lead to improvements in wellbore strengthening and lost circulation material recycling applications.
Directional Drilling Tests in Concrete Blocks Yield Precise Measurements of Borehole Position and Quality
Authors: Stockhausen Ed , Lowdon Ross , Lesso Bill 
Published: March 2012

Abstract
Directional drilling is accomplished by causing a mechanical or hydraulic deflection of the bit during drilling. Predicting BHA behavior prior to drilling and taking survey check-shots while drilling is common practice because understanding the directional tendency of a BHA is critical to successful well placement.
It has been suspected that different modes of drilling cause a near instantaneous change in the size, shape and centerline position of the borehole and, thus, change BHA tendencies. This is not backed up by continuous MWD inclination data which shows a long transition between the slide/rotate zones.
Since examining a wellbore to accurately determine these effects is impractical, a logical approach would be to set up a directional drilling process where the wellbore could be dissected and examined. Precise measurements of the wellbore centerline, diameter or circumference can be made under laboratory conditions and compared to field sensor measurements to determine the accuracy of the field measurements in terms of wellbore position, tortuosity and rugosity. Schlumberger developed a directional drilling test capability utilizing concrete blocks placed sequentially and drilled horizontally. The blocks can be positioned to accommodate changes in wellpath. They are sealed to allow mud flow during the drilling and then broken apart for extensive laser measurements and scans. The blocks are tagged to allow surveying to maintain a 3D coordinate system to millimeter accuracy.
Chevron and Schlumberger conducted a series of drilling tests to evaluate wellbores drilled with positive displacement motors (PDM’s). The blocks were drilled with slide/rotate sequences with up to 10 deg/100ft curve rates. Multiple MWD directional surveys were taken and compared to the actual position of the wellbore from the lab measurements.
This paper discusses the TVD accuracy of the well as a function of different survey spacing and its impact on horizontal well placement. Changes in touch points of the BHA within the varying hole diameter of the slide/rotate sections are also discussed. Metrics are proposed for managing wellbore quality in terms of tortuosity and rugosity along with their impact on the wider drilling community.
Continuous Circulation Drill String Sub
Authors: Weir J. , Goodwin R. , Macmillan R. 
Published: March 2012

Abstract
There is an increasing need to drill difficult reservoirs in a cost effective way. Over the past few years Managed Pressure Drilling (MPD) has made it possible to drill reservoirs which have a narrow window between pore and fracture pressure gradients. Before the introduction of MPD techniques, safely drilling and completing these formations was very costly and not always successful. Cycling the mud pumps off and on for connections affects the pressure and is a major problem for MPD. Techniques and equipment have been developed to make a connection while continuing to circulate the drilling mud to maintain constant pressure. Since 2005, the Continuous Circulation System (CCS) has allowed continuous circulation during connections with traditional jointed drill pipe, by using a chamber around the connection. Several companies have developed continuous circulation subs which are threaded between tool joints to achieve continuous circulation without a pressure chamber. These have had varying degrees of success from both an operational and safety standpoint. This paper describes the current MPD market and describes the philosophy adopted for a new side-entry sub.
Qualification of a 4.75 in. Rotary Steerable System for Complex 3D and High Build-up-Rate Applications in through Tubing Drilling (TTD) Operations
Authors: Eidem Morten , Andersen Stein Kristian , Winterstø Knut Morten , Schwartze Sascha , Clemmensen Carl C. , Nesheim Anders 
Published: March 2012

Abstract
Maturing of fields in the North Sea has led to a drive for technologies to extend field life and improve recovery rates. Through Tubing Drilling (TTD) is one technology which shows particular potential with regards to accessing bypassed oil and multiple small targets. TTD consists of two closely related technologies, coiled tubing drilling (CTD) and through tubing rotational drilling (TTRD). These technologies allow for re-entry through existing wells and drilling of one or more laterals from the existing well bore, while the old completion and Xmas tree remain in place. With the kick-off point below the production packer and subsequently close to depleted/over-pressurized zones or water, a high dogleg RSS is required based on the fact that a motor with bend causes high risk of damaging the crown plug seal area in the horizontal Christmas tree.
The Operator has for several years supported the industry in order to qualify a high dogleg Rotary Steerable System (RSS) with a motor to achieve the following:
– Perform subsea TTRD through 5.75 in. restrictions and with 15 deg/30 m dogleg capability. Consistent dogleg capability of 12 deg/30 m or more will enable TTRD in about 50 % more wells, compared to having a dogleg capability of 6 deg/30 m. – Minimize tubing wear during TTRD by combining motor and RSS. – High RSS reliability. – Enable use of RSS in CTD operations.
In collaboration with the Service company a modified 4.75in. RSS combined with a downhole motor successfully achieved the following objectives:
– Demonstrate max build-up and dogleg of 15 deg/30 m in wells with 5.75 in. pass through. – Verify capability of performing CTD, with regards to high dogleg capability with low weight on bit. – Demonstrate drilling capabilities with motor and with low RPM – Demonstrate capability of holding tangent. – Verify long life time.
A New, Alternative Weighting Material for Drilling Fluids
Authors: Al-Bagoury Mohamed , Steele Chris 
Published: March 2012

Abstract
Barite has been used to increase the density of drilling fluids (DF) since 1922. However, circumstances & needs are changing:
The API has recently introduced a new standard for 4.10 sg barite in recognition of diminishing supplies of readily available barite that meet API’s standard minimum density specification of 4.20 sg - high quality barite is running out. The search for new hydrocarbon resources to replace reserves has resulted in more difficult drilling conditions & fluid requirements e.g. deepwater, ERD, HPHT etc., where ECD management, sag control & formation damage mitigation are critical to success.
Alternative weighting materials (WM) such as manganese tetraoxide, treated micronized barite & cesium formate have been successfully used to handle many of the problems mentioned, but they are expensive & not produced in large volumes. Therefore, their application tends to be restricted. There is, therefore, a need for alternative weighting materials capable of providing better functionality than barite, but available in sufficient volumes to meet requirements & be competitively priced.
This paper describes a new micronized, weighting agent, suitable for use in drilling & completion fluids, which offers significant advantages in the control of ECD, sag & formation damage. It is denser than barite, acid soluble, available in large volumes of &gt; 100,000 tpa and is significantly cheaper than the current, high-end weighting materials.
Test results are given showing stable fluids with low plastic viscosity, gel strengths & sag, even under HPHT conditions, for both aqueous & non-aqueous based fluids. The material has an excellent HSE profile & is soluble in oilfield acids. Accordingly, it provides a viable alternative product, intermediate between barite & the more expensive weighting materials.
Integrated Pressure Management Processes for Reducing the Risk Associated with Well Instability Issues: Implications for HPHT Wells
Authors: Figenschou Jorunn Haver , Thorsen Arve K. , Thistle Bruce , Williams Urban 
Published: March 2012

Abstract
Optimizing well control processes are critical in high-temperature/high-pressure (HPHT) drilling operations so they do not encounter high cost overruns and compromise safety. The key to success is recognizing and mitigating challenges and associated risks early to adequately optimize drilling operations. This leads to a more effective drilling operation with reduced risk, increased safety margins and increased probability of successfully achieving the well’s objectives.
This case describes an integrated work process that has been implemented, incorporating pre-drill and real-time pore pressure prediction with proactive equivalent circulating density (ECD) management during well planning and drilling operations. This work process is especially important for optimizing drilling fluid properties to retain the drilling parameters within a safe operating mud window identified by real-time pore pressure and wellbore stability prediction. Operating in this safe window enables reduction in wellbore instability, formation damage, hole cleaning inefficiencies and poor drilling performance, resulting in improved safety margins, reduced risk, improved drilling performance and reduction in non-productive-time (NPT).
Several recent examples from Suncor Energy Norge HPHT wells are presented to illustrate the success of utilizing this integrated approach, resulting in drilling HPHT wells with no formation pressure-related NPT. The process begins with identifying pressure-related challenges in the pre-drill planning phase, optimizing the drilling process by validating, defining and maintain the drilling parameters within the safe operational window through an integration of proactive real-time pore pressure prediction and ECD management using all available LWD measurements: acoustic, gamma, resistivity, density, formation pressure while drilling, imaging, ECD, and temperature. Analysis is performed on mud logging data such as gas, the drilling exponent, cuttings and borehole caving and surface drilling data. Finally, lessons learned are captured that will further improve drilling efficiency and best practices in upcoming drilling campaigns.