bluuebunny/crossref_metadata_2025_split huggingface dataset:
A Quick Analysis of Pore Pressure Change and Formation Strain of Overburden Formation during Production and Injection
Authors: Morita Nobuo , Fuh Giin-Fa 
Published: August 2014

Abstract
When reservoir compaction occurs during production, the overburden formation deformation results in ocean floor subsidence and lateral movement. When a long term water or CO2 injection operation is performed, the overburden formation becomes unstable due to the reservoir expansion. These field operations induce formation strain and pore pressure change in all overburden formations. Predicting the magnitude of formation strain and pore pressure change is important for analysis of borehole stability, casing stability and overburden formation stability.
Two methods are developed in this paper. One is an analytical method assuming no mechanical property contrast between overburden and reservoir formations. The other is a set of figures created by a numerical model for predicting formation strains and pore pressure change during compaction and expansion with mechanical property contrast between overburden and reservoir formations. The parameter analyses give the following results:
Formation strain becomes significantly large if the Young's modulus of overburden formation becomes small. The casing design must be conducted including the formation strain of cap rock. If the shear modulus between overburden and reservoir formations is similar, the pore pressure increases at the overburden formations. However, if the difference of the shear modulus is large, the pore pressure decreases in the upper and lower cap rock with reservoir compaction. This new finding may change our common sense of pore pressure change of shale section around a reservoir.
This paper provides a set of equations and figures to quickly predict the pore pressure change and formation strain focusing on overburden formation where casing and formation stability problems are induced during production and injection operations. If the quick analysis indicates that the overburden strain and pore pressure change significantly affect the field operations, comprehensive analysis must be conducted with a geomechanical finite element model using a super computer.
Optimization of Drilling Method and Well Design to Drill Deep Well with Limited Equipment Capacity
Authors: Intrachai Kawin , Arkayamas Panit 
Published: August 2014

Abstract
One of PTTEP's joint operating company in MTJDA within the Gulf of Thailand has had the obligation to supply gas at its maximum capacity at all times and exploring the deeper territories is the only approach to acquire new reserves within the confined development area. This results in some complications both in drilling engineering and operation, which generally requires larger rig with higher day rate and more expensive technologies.
After the operator successfully drilled and completed Muda-9, one of the deepest exploratory wells in term of vertical depth in Muda field, in 2011 with 7,500 psi rig, the operator intended to drill MDE-13, a development well of the same vertical depth, in reference to Muda-9 with a smaller rig of 5,000 psi capacity, having a long term contract with the operator. MDE-13 having a planned depth of 3,065 mTVD/4,207 mMD became the first 5 casing strings for the operator's development well with the highest pressure of approximately 1.85 SG or 8,200 psi at TD. To prepare for drilling MDE-13, there were several concerns during the well design stage relating to rig pump capacity, narrow margin between pore and fracture pressure, an extremely small hydraulic fracturing target, higher temperature, and strength of tubing cement. With the comprehensive well design and the use of proper equipment, however, the operator lessened the associated risks to the acceptable level and the actual drilling operation went well without any major down time. In fact, the normalized time taken to drill MDE-13 is approximately the same as the time taken to drill Muda-9 despite the utilization of smaller rig and much stringent directional control, resulting in the estimate cost saving of the rig day rate of approximately 1 MMUSD.
The main objective of this paper is to present how the operator designed and drilled one of its most difficult wells successfully deep into the proximity of higher pressure and temperature environment with a relatively small rig and equipment limitation while maintaining the acceptable safety standards. The well design and practices of this development well are intended primarily for wells drilled in Gulf of Thailand area.
Offshore Exploration Program Benefits From Rolling PDC Cutter Technology, Timor Sea Australia
Authors: Giumelli Martin , O'Shea Paul , Maliardi Alberto , Sosnowski Paul , Shepherd Aaron , Sadawarte Sagar Sudhakar , Scordella Maurizio 
Published: August 2014

Abstract
Exploration offshore Australia requires the operator to drill an 8½” vertical borehole through the difficult Plover sandstone. The highly abrasive formation, with unconfined compressive strength between 15–30kpsi, has been problematic causing extremely short PDC bit runs and low rates of penetration (ROP). Erratic torque response was causing a reduction in bottom hole assembly (BHA) performance and system reliability. The operator required a PDC bit solution to increase run lengths and ROP.
To solve the problems, a new system was devised that enables a PDC shearing element to fully rotate while drilling to increase cutting efficiency/bit durability while reducing frictional heat. To strategically position the rolling cutters (RC) to obtain maximum benefit, a forensic analysis was performed on PDCs used in offsets. After investigation, engineers identified accelerated wear flats in the shoulder area and a new PDC design (RC813) was implemented by positioning two 13mm rolling cutters in the shoulder area on each of the eight-blades. The target objectives would be to drill the 8½” hole section through the Plover with one PDC bit and improve ROP.
The first well required one conventional PDC and one RC813 to drill through the Plover to TD. The standard PDC (10blades/16mm) drilled 90m (3739–3829m) at an average ROP of 5.4m/hr. The bit was pulled for low ROP and graded 8–3-CR-C-X-IN-BT-PR. The rolling cutter equipped RC813 drilled 126m (3829–3955m) at a ROP of 4.3m/hr. The RC813 was pulled in good condition and dull graded 1-2-CT-S-X-IN-PN-TD.
Parameter/bit adjustments in the second well enabled an RC813 to drill the entire Plover interval (3283m–3425m) in one run at an ROP of 9.26m/hr. The rolling cutter PDC bit run was 319% faster than a direct offset that required four standard bits to TD the section at an average ROP of 3.1m/hr. The RC813 torque response was smooth compared to erratic torque response of standard PDC in Plover. The increased meterage and ROP saved the operator over $1million USD.
Experimental Study of Gas Migration Prevention Through Cement Slurry Using Hydroxypropylmethylcellulose
Authors: Abbas Ghulam , Irawan Sonny , Kumar S. , Kalwar Shuaib A. 
Published: August 2014

Abstract
Gas migration during primary cementing is considered as an oil and gas industrial problem for many years. Currently, the gas migration problem is mitigated using modified cellulose based polymer (synthesized with carbonates) in cement slurry at high temperature. However, there is no widely accepted single polymer that can prevent gas migration without synthesization for high temperature cementing application.
This study presents an experimental investigation for prevention of gas migration through cement column during transition state of cement slurry. A natural polymer Hydroxypropylmethylcellulose (HPMC) is used for the first time ever as a cement additive to achieve desire prevention, which is stable at high temperature. The gas migration through cement slurry was determined using Cement Hydration Analyzer (CHA). HPMC was found to develop an impermeable barrier for prevention of gas migration. The experimental results showed that HPMC based cement slurry was gas tight as pore pressure remains low as 16 psi with constant gas injection of 150 psi for continues 08 hours. Further, API properties of cement slurries were determined using 0.20 to 0.50 gallon per sack of HPMC. The test results showed 04 to 06 hours thickening time, less than 30 minutes transition time, low fluid loss and high compressive strength at 190 °F. It is concluded that HPMC prevents the gas migration and significantly improves the API properties of cement slurry. In field applications, the presented HPMC polymer can simplify the design of cement slurry and prevent gas migration through cement slurry at high temperature.
Fatigue Strength Evaluation of Drill Pipe for Challenging Scientific Drilling Operations
Authors: Inoue Tomoya , Sakura Koji , Fukui Toshihiko , Kyo Masanori 
Published: August 2014

Abstract
The scientific drilling vessel Chikyu is performing challenging deep and harsh drilling activities. Generally, the fatigue strength of a drill pipe is a critical factor governing the performance of challenging deep drillings. Authors therefore established the evaluation method of the cumulative fatigue of the drill pipe and the drilling programs including the drill string configurations are planned based on the evaluation. The bending stress distribution of a drill pipe, which refers to the maximum locus of the bending stress during the drilling operation, was analyzed considering interference of the drill string with the structure, riser or drilling equipment. The occurrence probability of ship inclination due to ship motions and ocean current, the occurrence probability of the bending stresses, and the axial dynamic stress and its occurrence probability were analyzed. Consequently, the cumulative damage ratio and the possible duration of operation were obtained.
This study focused on the strength evaluation of the drill pipe for challenging scientific drilling operation at Nankai Trough that is a harsh environment because of the strong ocean current. From the results, we confirmed how severe the challenging scientific drillings are.
Optimizing Well Design in Saudi Arabia: Successful Application of Managed Pressure Drilling Enables Drilling Across Multiple Pressure Zones and Running Liner Using Constant Bottom-Hole Pressure Technique
Authors: Pinero Zambrano N. O. , Al-Ageel I. M. , Muqeem M. A. , Al-Mutawa A. S. , Mazouz C. M. , Hadj-Moussa A. , Zeb A. , Al-Ghamdi F. 
Published: August 2014

Abstract
Khurais field has seen, on an average, a 35% increase in reservoir pressure during the past three years due to water injection for production maintenance. A workover campaign started two years ago to reenter and workover some of the power water injection (PWI) wells. The campaign saw a dramatic increase in non-productive time (NPT) due to differential sticking and loss of circulation as well as difficulty in working over these wells conventionally.
Subsequently, Saudi Aramco started a campaign in late 2012 to workover these wells utilizing managed pressure drilling (MPD). MPD has enabled personnel to workover these wells at a 20% reduced mud weight, preventing stuck pipe and fishing related NPT.
This paper summarizes Saudi Aramco's experience gained during the working over of a well where drilling two formations together enabled the target hole size to be maintained as well as eliminating running the expandable liner for pressure isolation between these two zones. It further highlights the operational complexity and the challenges faced during the implementation of this technology while drilling the two formations with varying pore pressures. It also elaborates on the interdisciplinary team that was instrumental behind the safe and successful implementation of managed pressure drilling.
The paper also elaborates on the lessons learned and how they were implemented continuously with regard to health, safety and environment (HSE) during the workover operations. The long-term goal was to evaluate whether the application of MPD can be extended to other asset teams/areas effectively to reap its potential benefit.
Using High-Strength Dissolvable Metals to Increase Flow Assurance in High-Temperature and High-Pressure Environments
Authors: Carrejo N. , Kellogg B. R. , Gaudette S. L. , Barnard J. J. 
Published: August 2014

Abstract
Increased completion of ultra-deep, high-pressure and high-temperature wells is driven by the growing demand for hydrocarbons. Extreme pressure frac screens (XPFS) have been developed to handle the higher loads and conditions. An XPFS is a high-pressure-rated sand control screen capable of withstanding up to 15 ksi burst and collapse. The XPFS utilizes engineered, high-strength disintegrating materials (HSDM) to operate as a fluid-loss barrier that can be run-in on the liner. This new technology combines ease of use with a controlled delay in the activation that opens the screen to flow. The HSDM covers and seals over a bonded bead matrix that, when the HSDM dissolves, acts as a screen equal in filtration performance, but better than current sand control alternatives in its erosion resistance. The beaded matrix can be customized to ensure filtration through a wide range of particulate sizes and prevents passage of 85 to 90% of all particulates larger than 53µm. The HSDM covering the beaded matrix is formulated to corrode in the presence of brine and/or acid and provide access to the sand control media, enabling normal well production. The system increases the efficiency of hydraulic fracturing treatments, and can be installed in a steerable drilling liner. Alternatively, the beaded matrix can be replaced with a solid HSDM plug, thus acting as a fluid-loss friendly; solid-base pipe during run-in and leaving a pre-drilled liner after the HSDM dissolves, eliminating the expensive need to later perforate the pipe. This paper presents the pressure rating, dependability, and sand control capabilities of a liner that provides operators with an interventionless ability to complete ultra-deep, high-pressure high-temperature wells.
Gulf of Thailand Case Study: Improving Zonal Isolation with an Advanced yet Simplified Cementing System
Authors: Rivera N. N. , Siritheerasas K. , Valentino V. , Fauchille G. , Thein A. , Stanley R. , Brandl A. 
Published: August 2014

Abstract
The Gulf of Thailand is characterized by shallow-water depth wells with bottomhole static temperature ranging from 240 to more than 420°F. These wells are drilled to an average of 12,000 ft MD and 9,000 ft TVD with a fast paced-batch drilling strategy. Most cement jobs are done offline, and on the surface section can be as frequent as 6 jobs per day. With multiple rigs, operators can require more than 100 cementing operations per month and cement volumes as high as 18,000 bbl. This efficient operations environment creates a demand for a logistically and operationally simple cement system that can be applied in all well sections and across the full range of expected temperatures. An advanced, lightweight seawater-based cementing concept was tested for this application. This new cementing system uses a single blend with only 3 to 4 primary liquid additives (including a stable, high-temperature, multi-functional polymer) to adjust all primary cement jobs for the entire wellbore. A sophisticated lab testing program was conducted for the innovative cementing concept according to the required demands on cement slurry design given the harsh wellbore conditions in the Gulf of Thailand. Tests revealed that the developed cementing systems meet all well requirements despite low densities of 13.3 to 14.0 ppg with high water content. This advanced cementing system was introduced in 2011 and has gradually been used on all wells since then – to date more than 500 wells in the Gulf of Thailand. In addition to improving logistics, use of the system has enhanced cement bond quality in production tubing cementing jobs. This improvement also reduced pay at risk due to insufficient cement isolation. This is evident in the whole range of well temperatures.
Advanced Technologies and Practical Solutions for Challenging Drilling Applications
Authors: Jellison M. J. , Chan A. 
Published: August 2014

Abstract
This paper provides a review of recent technology advancements and addresses practical considerations associated with drillpipe and drill stem components for extreme drilling applications. Ultra-high torque double-shoulder rotary connections are often employed in these applications. Recent developments and enchantments in these connection designs including new higher strength materials, advanced thread forms and associated improvements in torsional strength and fatigue performance are presented. Deepwater wells frequently require long, heavy casing strings to achieve the total depth objectives. High capacity landing strings capable of running these heavy strings with total hook loads approaching 2.5 million pounds have been successfully developed to address this well design challenge. The paper discusses the engineering solutions implemented to overcome the high forces, slip crushing concerns and material strength and toughness considerations for these critical applications.
Due to the dramatic increase in oil prices the industry has seen a re-emergence of deep and ultra-deep drilling projects that encounter H2S gas. The paper provides an update on the latest sulphide stress cracking (SSC) resistant drillpipe grades including the first fully SSC resistant drill pipe system with SSC resistant friction welds joining the drill pipe tubes and tool joints. Major operators have been using a drill pipe based riser system for intervention and completion work in the waters offshore Brazil, Australia, Africa and other deepwater basins around the world. The paper provides updates on design improvements of high pressure capacity connectors and advanced materials for these critical riser applications.
Deepwater and other critical wells often encounter abrasive formations, high side loads between the drill string and bore hole and other conditions that promote drill stem friction heating failures. The paper includes characteristic features of these failures along with case histories and prevention methods.
Disappearing Tubing Hanger Plug (DTHP) Improves Well Integrity and Saves Rig Time for Deepwater Well Completions
Authors: Sevatdal Sigmund , Chanaani Rachid , Koay Darren 
Published: August 2014

Abstract
Traditionally, to complete a subsea well with a vertical Christmas tree, it is necessary to land the tubing hanger and install and pressure test a wireline set tubing hanger plug. Once the plug is tested, the subsea BOP can be removed, the vertical Christmas tree can be installed, and the plug retrieved through the work-over riser before the well is ready for production or injection. This is a time consuming rig operation requiring additional handling of the work-over riser and wireline run, which increases both the HSE and operational risks. With increasing focus being placed on the safety, reliability and cost efficiency of deepwater developments, it is critical that the operational risk and rig time for drilling and completions is reduced.
This paper describes the innovative invention of a shallow set barrier plug – the Disappearing Tubing Hanger Plug (DTHP) – and includes a case study of the first application of the plug on Akpo-214. This ground-breaking solution, based on knowledge of the existing glass barrier plug technology, was developed through a collaboration between Total E&P Nigeria and TCO. The objective of the invention is to provide a more reliable and cost effective solution for deepwater completions offshore of Nigeria.
The application of the DTHP has proven that the disappearing feature of the DTHP with pressure cycling is effective and reliable. The pressure cycle was applied directly from the FPSO, liberating the expensive rig for other purposes. The DTHP also provides improved well integrity by forming an ISO14310 V0 qualified gas-tight barrier. The operator saved rig time for the first installation and the rig time saving is estimated to be mutiple days for an optimized completin sequence on deepwater applications, which directly translates into savings of millions of USD.
"The Story of Bluegrass:" Carlton Haney, Bill Monroe, and Redemption Drama in the First Bluegrass Festivals
Authors: Roach Ron R. 
Published: August 2014

Abstract
Appalachia has been fertile ground for the development of distinctive American music, and two of the forms of music most closely associated with the region are country and bluegrass. Promoter Carlton Haney, a member of the Bluegrass Hall of Fame, was a significant figure in each of these musical genres, playing a major role in developing the careers of such performers as Loretta Lynn, Porter Wagoner, Merle Haggard, Conway Twitty, Reno and Smiley, and Bill Monroe. In 1965, Haney founded the world’s first multiday bluegrass festival in Fincastle, Virginia, and held important festivals into the 1970s, starting a movement that helped to define modern bluegrass and introduce it to a national audience. One of the most memorable features of Haney’s early bluegrass festivals was "The Story of Bluegrass," a musical narrative recounting the creation of bluegrass as a musical genre. This paper uses the rhetorical theories of Kenneth Burke to examine "The Story of Bluegrass" as a redemption drama that played an important role in shaping bluegrass music and the legacy of Bill Monroe.
Constitutionele antwoorden op toenemend pluralistische samenlevingen
Authors: Zoethout Carla 
Published: August 2014

Constitutional answers to increasingly pluralistic societies. Religious diversity in France, Italy and Canada
In this article, the question is raised which constitutional answer to immigration is most sustainable with a view to future multicultural societies. I focus on the constitutional answers to immigration in France, Italy and Canada. In France, in 2010, legislation was adopted prohibiting the wearing of face-covering clothing in public. With this ban, the French intended to enhance the equal participation of citizens in society and to protect the equality of the sexes. In Italy, a heated debate took place about the display of crucifixes in (public) schools, which resulted in a restoration of the predominance of the Catholic religion. Across the ocean, in the Canadian province of Québec, the National Assembly of Québec has been discussing a ‘Charter’, whose prevailing idea is to enhance the neutrality of the state, among others by prohibiting religious clothing in public institutions. The question is which of these approaches is best defensible to regulate a society, which will undoubtedly become even more diverse in the near future.
Dossier imamopleiding: het Nederlandse ‘imamopleidingsdebat’ in historisch perspectief
Authors: Boender Welmoet 
Published: August 2014

The Dutch debate on Imam training programs in a historical perspective
In 2005 and 2006 three state-funded Islam- and imam training programs started at Amsterdam Free University, Leiden University and Hogeschool Inholland, after more than two decades of political and public debate. These confessional programs were to educate a Dutch ‘polder imam’. Recently however, the closure of two programs was announced.This article places the establishment as well as the closure of these programs in a historical perspective. It explores two striking parallels between the motivations in favor of an imam training and the ways the Dutch state has dealt with the institutionalization of religious plurality in the nineteenth and twentieth centuries.