bluuebunny/crossref_metadata_2025_split huggingface dataset:
Casing Drilling 24-in. Surface Section Enables Operator to Add One Extra Slot to the Existing Drilling Template and Cut Operation Costs Offshore Congo
Authors: De Luca Stefano , Aliko Enis 
Published: March 2009

Abstract
Foukanda permit is situated offshore Congo to the north of Kitina platform and to the west of Pointe Noire town. The Foukanda platform comprised a drilling template with eight slots, all of which were drilled through a 30-in. conductor casing that was laid on sea-bottom and connected to the platform's drilling template, and all were directional wells.
The operator wanted to drill another well to explore another structure of the reservoir, but this was not possible with the existing template. The custom way of securing an extra slot was that which involved setting of a 30-in. diverter with 2° angle to the sea bottom, conventionally drilling some length of new hole with a 26-in. roller cone bit and then running and cementing a 20-in. casing through this 30-in. diverter and with free returns to sea bottom. This method had a negative aspect, which was the difficulty of re-entering the 26-in. hole with the 20-in. casing because of the sag of the conventional drilling assembly at the exit of the 30-in. diverter.
To resolve this problem, the operator opted for an innovative drilling technique: drilling with casing. A 24-in. casing drilling bit was manufactured on purpose and was run through the diverter on a 20-in. casing string which drilled 66 m of new formation at 2° inclination and with returns to the seabed. The casing was cemented in place and the casing drilling bit was than successfully drilled out with a roller cone bit. This operation enabled the operator to secure the extra slot, to get out of the existing wells trajectory and to save the costs associated with difficulties to re-enter the hole.
In this paper, the authors will describe the casing drilling bit technology, the planning of operations, the implementation, and the results compared to conventional drilling.
Test of a BOP/Riser Connection with an External Inflate (EI) Inflatable Packer
Authors: Vaucher D. , Parrish C. , Brooks B. 
Published: March 2009

Abstract
With the oil and gas industry increasingly looking for energy offshore, there will be growing costs associated with the complexity of drilling below the ocean floor in deeper water. A leak detected after latching the lower marine riser package (LMRP) in deep water can cost the rig and the energy producer up to a staggering $12 million in lost time. Clearly, there is a need to be able to test the BOP/riser connection and cap seal for pressure integrity at surface before the operator runs to depth with the LMRP.
This paper describes a procedure to test at surface for leaks inside the BOP, at the cap seal and annular seal; all connections are tested offline and, most importantly, these tests do not interfere with drilling operations. This method is also safe and economical since it uses existing, field proven equipment and can be performed in as little as half an hour.
First, the tool is inflated inside the BOP, above the cap seal. Pressure is then applied from below the tool to test this seal's integrity.
The tool can then be inverted and placed higher up in the BOP in order to test any of the BOP/riser connections. In either position, by observing the applied pressure, it is possible to confirm the presence or absence of a leak, as well as its location. A case study is presented, showing conclusive results. Testing did detect the presence of a leak, which was fixed, and subsequent test runs did in fact confirm this.
Remotely Managing a Project in a Volatile Security Environment
Authors: Al Hashmy Louayd , Assalman Waleed , Sabah Marwan , Qutob Hani 
Published: March 2009

Abstract
Iraq is undergoing a period of transition after the overthrow of former regime. This created a vacuum of authority throughout the entire country which has lead to a dangerous security situation, posing serious risks to a range of targets, delaying reconstruction and making it very difficult to provide any services for developing the country.
Therefore, the lack of utilities, security and basic services has forced a significant portion of the skilled workforce to leave the country. Furthermore, oil and gas industry infrastructure was in a very poor state and required tremendous support of equipment and experienced manpower.
All the above factors prevented many major oil companies from operating and introducing their technology in Iraq. On the other hand, Weatherford was firmly committed to establishing their business inside Iraq but decided to control and manage their operations remotely rather than inside Iraq. More specifically, the management team was based in Dubai to plan, manage and support operations and an established team in Iraq to follow directions from management office.
Coordination of operations was done using state-of-the-art communication systems, effective information reporting procedures and experienced technical support on the ground. Field personnel were extensively trained through class-room and interactive sessions, as well as QHSE training to comply with Weatherford standards. Finally, an integrated project management system was created to provide clients with experienced project management, well engineering expertise and the optimum technology for integrated projects to jointly create greater value in an environmentally responsible manner. The positive outcomes are better access to technology, teamwork and an alliance spirit with mutually agreed objectives.
The many successes achieved through this remote management system demonstrate the effectiveness of Weatherford's approach in tackling the challenges of operating in a volatile security environment such as Iraq.
Development and Installation of an Extended Reach Multilateral Junction
Authors: Peterson Erick , McKeever Steve , Hartwig Dennis , Eggemeyer Jerome , Ortiz Alex , Pendleton Bryan , Martens Hal 
Published: March 2009

Abstract
A multitude of extended reach technologies have been utilized in the West Sak field on the North Slope of Alaska to reduce surface impact in a remote and environmentally sensitive area. Significant to the shallow heavy oil West Sak development is the use of multilateral horizontal wells with a junction providing mechanical support and both through-tubing lateral isolation and re-entry capabilities. However, as extended reach drilling capabilities evolved to routinely reach departure to true vertical depth ratios in excess of five to one, multilateral junction technology did not evolve at the same pace.
A new multilateral junction was designed to match current extended reach drilling capabilities and replace existing multilateral equipment which was utilized beyond its intended limit incurring both installation and production risk. The newly designed junction allows lateral liners to overcome drag limitations by rotating the liner and junction to setting depth in one trip and includes several positive indicators to ensure a successful installation.
This paper discusses the evolution of multilateral wells in the West Sak development, the limitations of multilateral junctions when utilized in extended reach wells, the development and testing of a new multilateral junction, and several successful field installations. Operation highlights during the completion phase of a multilateral well with a lateral departure to true vertical depth ratio in excess of six to one are included. Existing tools such as oil based mud lubricants and thorough torque and drag prediction were combined with the new junction for a successful completion which progressed the application for multilateral junctions in extended reach wells
Successful Drilling of a Deviated, Ultra-HTHP Well Using a Micronised Barite Fluid
Authors: Gregoire Michel , Hodder Mike , Peng Shuangjiu , Massam Jarrod 
Published: March 2009

Abstract
This paper reviews the design and application of a micronised barite fluid (MBF) to drill a deviated high-temperature, high-pressure (HTHP) well in the Northern North Sea. The key technical challenge was to avoid sag of the weight material. On a previous well, using an API-barite-weighted fluid, sag had resulted in considerable non-productive time.
The various fluid options were assessed by a technical prequalification exercise which involved extensive testing for viscosity, fluid loss and barite sag under simulated downhole conditions. The MBF was used to drill the 8½-in. section from 6,354 to 7,327 m; the deviation at the 9⅝-in. casing being 42 degrees. The bottomhole static temperature (BHST) was 205°C and maximum mud weight 2.15 sg.
The well was successfully drilled to TD, but two stuck-pipe incidents necessitated sidetracks. Despite these operational incidents, no significant sag occurred, and as a result, considerable time savings were achieved on flow checks, trips, and cementing operations and the required logging program could be performed.
Surface BOP System Operational Experience Offshore Brazil in 1,900 m of Water
Authors: Tarr B. A. , Taklo T. , Hudson A. , Stockwell L. , Schroeder J. 
Published: March 2009

AbstractThis paper presents the recent operational experience using a surface BOP system for both drilling and subsea completion activities offshore Brazil in the first phase of the Parque das Conchas development (block BC-10) that encompasses several reservoirs in up to 2,000 m of water.The Transocean GSF Arctic I, a moored rig capable of operating in 945 m of water using a conventional 18-3/4" subsea BOP stack and marine riser system was equipped with a pre-laid mooring system and surface BOP system especially designed for this project that could extended the rig's effective water depth capacity to as much as 2,250 m.Prior to the start of drilling operations a service vessel was used to pre-install the conductors for both the wells and the subsea pumps. In addition to taking these activities off the critical path, the precision achieved by using a subsea hammer to install the well conductors at each drill center minimized the time required to move from well to well for batch drilling and completion operations.The start up performance and learning's from the following new elements used in this project will be presented: Site specific pre-laid polyester taut-leg mooring systemSlim-bore wellhead system (to land production casing hanger)Purpose built 16" OD high pressure riser systemPressure test hose line, strapped to riser (to press. test tubing hanger & packer)Lower shear ram in SID replaced with fixed 7-5/8" pipe ram (to seal on slick joint)Power and hydraulic lines added into the SID umbilical (to reduced ROV support needed)Vertical subsea tree, Tubing Head Spool and slim bore tubing hanger with hydraulic running toolSpacer Spool (same height as Tubing Head Spool)The start up performance of this uniquely equipped rig system will be presented to show how attention to detail and a strong learning culture have paid handsome dividends.
Maintaining Steerability While Extending Gauge Length to Manage Whirl
Authors: Dupriest Fred E. , Sowers Steven F. 
Published: March 2009

Abstract
This paper discusses the results of a global campaign to increase the length of the gauge area of bits used on rotary steerable systems (RSS) to mitigate bit whirl and its undesirable effects. The desired steerability was achieved with lengths in excess of 4 in. with all RSS tools utilized. The modifications have resulted in reduced vibrations, significant improvement in drill rate, improved borehole quality, and reduced tool damage.
When the operator's performance management process was implemented, real-time and post drill analysis of mechanical specific energy suggested 40% of footage drilled worldwide was affected by bit whirl or lateral instability. One element in the programmatic response was an initiative beginning in 2006 to extend bit gauge lengths to constrain side-cutting and reduce the amplitude of whirl-induced patterns. The value of extended gauge lengths has been demonstrated in numerous papers, but field implementation by the industry has not been uniform, and a significant issue has been concern that steerability would be reduced. The purpose of the initiative was to demonstrate that common build rates could be achieved with all RSS tools used by the operator with bits having a minimum gauge length of 4 in. In the subject wells over a two year period normal build rates (3-5 deg/100 ft) were not affected with 4-in. gauges if the profile and aggressiveness were properly designed. The gauge profiles used to maintain steerability included full taper, full undercut, and partial undercut. While the desired steerability was achieved with both point-the-bit and push-the-bit RSS tools, specific modification required in the gauge profile varied with the RSS used, desired build rate, and drilling environment. Drill rate performance and bit life also improved, but this was partly attributed to implementation of the performance management process and specific rig crew training. Extension of the gauge length is also known to benefit bent motor operations5, but the effects of various gauge profiles are less certain and motor operations are not discussed in this paper.
The objective was not to determine the maximum build rates achievable, but to simply confirm that gauge lengths of 4 in. or greater could be used as standard practice in normal operations. This paper discusses the rationale for use of extended gauges, the modified profiles used to maintain steerability with various RSS tools, and the field performance achieved.
Dry Dope-Free OCTG Connections: A Novel Environmentally Friendly Technology Validated Through Diverse and Severe Field Conditions
Authors: Castiñeiras T. , Núñez A. , Gallo E. , Carcagno G. 
Published: March 2009

Abstract
The development of dope-free alternatives to standard thread compounds used for the assembling of OCTG connections (tubing & casing) started in the late 90's when some initial solutions were tried, being really commercially available from late 2003. The challenges from the galling resistance needs, as well as the handling and storage requirements, were addressed and the lessons learnt from initial uses and experiences were incorporated to define products that are reliable and have proven the suitability in different environments as those from the extremely humid and cold Barents Sea conditions to the sandy and hot environment in the Middle East. The extension and diversity of the uses and experiences collected today allows not only to confirm the validity of initial drivers for the development of this alternative, mainly related to the environmental care, but to detect and confirm additional benefits from the possibility of complete elimination of thread compound from the casing and tubing installation and storage process.
The dope-free solution demonstrated suitability for application in all tubing and casing dimensional ranges, and for all type of steels as common carbon steel (both API grades and proprietary), 13Cr, and Corrosion Resistance Alloys (CRA), in premium connections with metal-to metal seal, and big-OD semi-premium connections.
This paper describes the different experiences related to the field use of a fully-dry dope-free solution, the improvements and adjustments incorporated after initial experiences and operators feedback, the verification activities in laboratory, and especially in experimental rigs under actual field conditions, and summarizes the advantages and the value added through the use of this type of technology.
Targeting Challenges in Northern Areas Due to Degradation of Wellbore Positioning Accuracy
Authors: Bang J. , Torkildsen T. , Bruun B. T. , Hâvardstein S. T. 
Published: March 2009

Abstract
The surveyed position accuracy degrades when one approaches the magnetic and geographical poles. Both magnetic and gyroscopic tools are affected. We have analyzed the accuracy of several magnetic and gyroscopic services in a number of representative synthetic wellbores. Locations representative for the North Sea and the Barents Sea are chosen. The results show that an increase in horizontal target dimension by a factor of 2 is necessary when moving from 60°N to 75°N, to maintain the same hitting probability.
Examples of areas which may be affected by these findings, are: target design, well planning, surveying programs and practices, anti-collision criteria, and the ability to drill relief wells.
Pull Your BOP Stack—Or Not? A Systematic Method to Making This Multi-Million Dollar Decision
Authors: Sattler Jeff 
Published: March 2009

Abstract

Category: Deepwater Drilling or Case Studies
Pulling your BOP stack, particularly in deep water, is one of the singularly most costly events in the drilling of a well if it occurs. While in most cases this course of action is correctly undertaken, occasions occur when the stack pull could have been avoided. These regrettable incidents occur for a variety of reasons, including inadequate information and/or staff training, unclear understanding of regulatory or company requirements, and non-availability of experts to assist in the decision making due to time zone differences, among others.
This paper presents several case studies where planned stack pulls were circumvented or could have been, as well as a systematic protocol that can be developed prior to starting a well to define the decision making process for stack pulls for your specific program.
Drilling and Completing the First U.S. Offshore Gas Storage Wells in Mississippi Sound, Offshore Alabama
Authors: Fulks Robert , Cagle Douglas O. 
Published: March 2009

Abstract
In 2006 Falcon Gas Storage Company concluded a study of the Dauphin sands in the shallow waters of Mississippi Sound, Alabama. The study was conducted to determine if the depleted reservoir could be used as a gas storage facility. With preliminary seismic analysis indicating a suitable closed structure existed, further studies were done to determine the practicality of drilling and completing a series of shallow gas injection/producing wells. This paper addresses that feasibility and the subsequent well planning challenge which ensued.
Latest Enhancements in High Strength Sour Service Tubulars
Authors: Urband Bruce P. E. , Bernard Frédéric , Morey Steve , Bradley Bruce , Legay Frédéric , Marchebois Hervé , Linne Cédric , Lynn Garth 
Published: March 2009

Abstract
Today more deep water, high pressure high temperature (HPHT) wells are being drilled and completed in the presence of Hydrogen Sulfide (H2S), requiring an ever increasing volume of high strength ( &gt;=110 ksi ) sour service-rated tubulars. As this trend moved forward, suppliers overcame critical metallurgy challenges to improve the original offer in 110 ksi sour service materials, extending production toward thicker products and developing dedicated products such as 110 ksi for mild sour use, or thick DST strings used in extreme HPHT wells. These metallurgy improvements also paved the way to develop 125 ksi mild sour service grades. Based on these latest enhancements, and taking the traditional API grades as historical reference, the objective of this paper is to discuss various high strength sour service tubulars, their relative applicability in well conditions, basic manufacturing techniques to optimize tubular as well as the NACE testing performed to characterize the different sulfide stress cracking properties.
First Application in Mexico and New World Depth Record for MPD Concentric Nitrogen Injection to Drill Horizontal Wells in Low Pressure Reservoirs at Samaria Field
Authors: Urbieta A. , Lupo C. , Castellanos J. M. , Scarcelli D. , Ramirez O. , Puerto G. , Bedoya J. 
Published: March 2009

Abstract
Samaria oilfield, located in southern Mexico 20 km west of Villahermosa, Tabasco, with an area of about 160 km2 is one of the world's largest in extension and one of the oldest oilfields in Mexico, historic crude oil exploitation targets the Cretaceous Upper Medium and Lower (4200 mts TVD to 4500 mts TVD). Formation pressure in these naturally fractured carbonates has been decreasing over the last 20 years with current values down to 0.4 gr/cc. Managed Pressure Drilling (MPD) techniques are implemented using Nitrogen injected through Drill Pipe to avoid lost circulation, formation damage and differential sticking. However the significant amount of nitrogen inside the DP generates important limitations for current MWD tools. The need for Horizontal wells to increase the drainage area has become a priority for the Mexican National oil company thus directional control and LWD capabilities must be prioritized. The nitrogen concentric injection technique was then taken into consideration to bring solutions to the MWD pulse signal transmission and downhole temperature handicaps. This paper describes the experience gained in planning and executing the first horizontal well in the Samaria field using Nitrogen Concentric String injection also recorded as the deepest ever concentric injection point (4171 mts MD and 4117 mts TVD). The paper will guide the technical community over the design, planning and execution process: geological review and candidate selection, pre-engineering study, transient and steady state multiphase flow modeling, final drilling program, training, safety, contingencies, directional planning for geo-steering with MWD/LWD, lessons learned and production enhancement results.
Innovative Design Rotary Steerable Technologies Overcome Challenges of Complex Well Profiles in a Fast Growing Unconventional Resource— Woodford Shale
Authors: Janwadkar Sandeep , Hümmes Olof , Freyer Carsten , Rogers Tom , Simonton Steve , Black Don 
Published: March 2009

Abstract
Woodford Shale of Oklahoma is emerging as one of the fastest growing natural gas fields in North America because it has all the characteristics required for a profitable shale-gas play. More than $2 billion were spent in 2008 on some of the major productive intervals in this field. Although the upside potential is tremendous, efficient extraction of natural gas from the Woodford Shale poses several drilling and completion challenges. Low porosity and permeability limits well productivity. Complex well profiles and extended length laterals are required to maximize productivity. Long laterals posed several drilling challenges such as excessive slide drilling time, difficulty controlling well trajectory, unacceptably low penetration rates, high torque, and high drag. Engineers determined that wellbore tortuosity and high friction factors caused inefficient transfer of weight on bit and reduced rate of penetration (ROP). Existing rotary steerable systems available are typically cost prohibitive for this application/environment. To overcome these challenges, research, field testing and several years of experience gained with other automated rotating and non-rotating rib steering systems has culminated in the development of a new state-of-the-art rotary steerable closed-loop system (RCLS). This system, specifically designed for 3D wellbores for rotary steerable directional drilling in low spread cost land-drilling applications uses an automated rib-steering closed-loop system. Since the introduction of this innovative system, many wells have been drilled in North America with build/drop of 8°/100 ft. Bottomhole assembly (BHA) modeling software with finite element analysis was used to optimize BHA design. This strategy has been implemented to drill several wells in the Woodford Shale with excellent results. The new design of RCLS coupled with advanced BHA modeling software has significantly improved the drilling performance. The results achieved are excellent control over the well trajectory in the curve and lateral, improved transfer of weight to the bit, minimum torque and drag. Drilling complex well profiles have increased the length of laterals by several hundred feet. This has enabled additional recovery of gas, and the days required to drill the lateral interval have been reduced by more than five days.