bluuebunny/crossref_metadata_2025_split huggingface dataset:
Managing Change in Difficult Times
Authors: Johansson Jan Erik 
Published: February 2015

Management
The recent economic crisis provided a sense of urgency that helped organizations everywhere to successfully implement changes that would have been difficult otherwise. Companies spanning all global geographies and across all market segments, including energy, are being forced to examine the fault lines in their business under the pressure of sharply reduced demand, the failure of suppliers and partners, limited access to finance, and other consequences of the downturn. Many firms find this an inauspicious environment in which to attempt fundamental change in processes, behaviors, or structures, for fear of subjecting the organization to even greater strain. Others, however, see the crisis as a unique opportunity to achieve just that.
To assess the degree of change that firms have been experiencing since the onset of the economic crisis, and how they are handling its internal consequences, the Economist Intelligence Unit surveyed more than 500 European and US executives in July and August 2009 as part of Celerant Consulting’s second annual global survey on change.
More than half (59%) of global business executives who responded to the survey say that the current economic crisis has revealed shortcomings in their organization that they are attempting to redress and two-thirds (66%) of participants state that their organization is using the crisis as an opportunity to drive change that would have been difficult to achieve in better times.
Maintaining Change Programs
During times of economic uncertainty it is common for companies to attempt to simply weather the storm and not invest in organizational changes that will ultimately result in more efficient and effective business practices. However, the survey reveals that only 6% of firms have suspended change programs—structured approaches to implementing and managing change within a company—as a result of the financial crisis and the majority (60%) of firms are continuing with and even accelerating existing change programs while also launching new ones.
There is a danger, however, that firms are using the crisis to launch change initiatives too rapidly, with too heavy a focus on short-term objectives which yield only one-time saving rather than creating sustainable cost improvements that will continue over time. More than half of respondents in the survey confirmed this.
Drilling a Hole in Granite Submerged in Water By Use of CO2 Laser
Authors: Bybee Karen 
Published: February 2015

This article, written by Assistant Technology Editor Karen Bybee, contains highlights of paper SPE 119914, ’Drilling a 2-inch in Diameter Hole in Granites Submerged in Water by CO2 Lasers,’ by Toshio Kobayashi, SPE, and Masahiro Nakamura, Japan Drilling Company, and Satoshi Kubo and Makoto Ichikawa, SPE, Japan Oil, Gas, and Metals National Corporation, originally prepared for the 2009 SPE/IADC Drilling Conference and Exhibition, Amsterdam, 17-19 March. The paper has not been peer reviewed.
As part of a fundamental study of rock drilling by laser irradiation, the full-length paper describes laser drilling of a 5.08-cm-diameter hole in granites submerged in water. The laser beams melted the granite surface locally to form small glassy beads. Repetition of this procedure demonstrated that a high-power laser beam propagating in water can be used to generate a hole in rocks.
Experimental
A 10.6-µm carbon dioxide (CO2) laser was used. The laser had a 5-kW peak-output power, a 5-ms pulse width, a 10-Hz repetition rate, a 250-J pulsed energy, and a 50% duty ratio. The CO2 laser has a ring mode. A laser-irradiation nozzle with a 20-in. focal length was used for irradiation in air and in water. For irradiation in water, a 300-mm3 acrylics chamber was used. A high-speed video camera was placed at the side of the chamber to photograph the dynamic behavior of the formation of bubbles induced by laser irradiation. A rock specimen was placed in the chamber so that the distance from the water surface to the top surface of the granite was 50 mm. The CO2 laser was intermittently irradiated perpendicularly from a muddy-water surface. The irradiated laser beam was absorbed in the water and formed cone-shaped bubbles that had an irregular interface. Because the induced bubbles kept their shape until a subsequent laser beam reached the rock, the laser beam could drill the rock effectively.
Rock Specimens
Inada granite was selected as a rock specimen because the Inada granite is representative of quartz-group minerals and quartz-bearing rocks in Japan. Its K-Ar chronology is 60 Ma. Inada granite often is used as construction materials and experimental materials. The Inada granite contains 33.7% quartz, 32.1% potash feldspar, 30.3% plagioclase, and 3.8% biotite. Physical characteristics of Inada granite are as follows: 180-MPa uniaxial compressive strength, 0.75-MPa split-ting tensile strength, 65-GPa Young’s modulus, 2.63 g/cm3, 0.75% porosity, 0.0167- to 0.0377-J/(g-K) specific heat, and 54.4- to 83.7-W/(m.K) thermal conductivity.
Results and Discussion
In earlier experiments with Inada granite irradiated in air with a CO2 laser, transparent glassy objects crystallized on the walls of the created hole. It was observed that the fused Inada granite could not fully flow out of the hole, solidifying on the bottom to close the bottom of the hole. As a result, a complete hole cannot be created by the laser irradiation in air.
Post-Mortem Analysis of MODUs in Hurricanes Katrina and Rita
Authors: Denney Dennis 
Published: February 2015

This article, written by Senior Technology Editor Dennis Denney, contains highlights of paper OTC 20144, ’Post-Mortem Analysis of MODUs in Hurricanes Katrina and Rita,’ by Malcolm Sharples, Offshore: Risk and Technology Consulting and John Stiff, ABSG Consulting, prepared for the 2009 Offshore Technology Conference, Houston, 4-7 May. The paper has not been peer reviewed.
Several hurricanes have passed through the Gulf of Mexico (GOM) resulting in mobile offshore drilling units (MODUs) parting moorings or collapsing, but none have come close to the devastation caused by Hurricanes Katrina and Rita, in August and September 2005. Twenty semisubmersible MODUs suffered significant mooring impairment, and eight jackups were declared total losses (with many more suffering additional settlement and other damage). In the aftermath of these hurricanes, which followed Hurricanes Lili and Ivan, the industry re-examined and upgraded the standards for setting MODUs.
Overview of Hurricanes Katrina and Rita
In August 2005, Hurricane Katrina moved through the US GOM. Katrina was the second Category-5 hurricane of the 2005 Atlantic season. In September 2005, Hurricane Rita also tracked through the GOM. Hurricane Rita reached Category-5 strength before entering the warm waters of the oil- and gas-exploration regions in the central GOM where it passed over the deeper outer-continental-shelf (OCS) structures as a Category-4 hurricane. Rita weakened to a Category 3 before making landfall along the upper coast of Texas.
Sixteen semisubmersible MODUs were in the vicinity of Hurricane Katrina, with two other MODUs stacked, undergoing repairs. Of these MODUs, five suffered complete mooring failure, two had partial failure, and one incurred limited anchor slippage. Most of the semisubmersibles were on the less-severe west side of the storm track. However, Hurricane Rita passed to the south of most of the semisubmersible MODU fleet leading to more MODUs being exposed to severe conditions. Seven semisubmersibles suffered complete mooring failure, four suffered partial failure, and one had limited anchor slippage.
The route of Hurricane Rita probably was the worst possible regarding the number of jackups exposed. Many of the jackups were in water depths where the storm was greater than the design extremes, and in many cases the storm was greater than the 100-year extreme for the location. During these hurricanes, there were approximately 90 jackups in the GOM. Of those, 25 jackups were impacted by Katrina and 54 were impacted by Rita. Two were a total loss in Katrina, and six were a total loss in Rita. Of those that survived impact, seven were “surprising survivals” in Hurricane Katrina and sixteen were surprising survivals in Hurricane Rita. Of the jackups damaged, but not destroyed, only three independent-leg jackups and two mat-supported jackups needed to return to the shipyard for repair. Five independent-leg jackups and four mat-supported jackups were repaired on location and returned to work.
MA D6: A Fast-Track Deepwater Project
Authors: Bybee Karen 
Published: February 2015

This article, written by Assistant Technology Editor Karen Bybee, contains highlights of paper OTC 20174, ’MA D6 - Going Beyond the Limits of Deep Water Fast Track Projects,’ by Georges Michel, Willy Gauttier, and Pierre Savy, Technip, originally prepared for the 2009 Offshore Technology Conference, Houston, 4-7 May. The paper has not been peer reviewed.
The MA D6 field-development project in 1100 m of water is the first deepwater development on the east coast of India. The MA D6 project has been one of the fastest deepwater projects of its size involving a large amount of technical content in a location with minimal established infrastructure. The full-length paper describes the technical aspects of the project and the resulting designs that were selected, and it outlines the logistical issues associated with this first deepwater and fast-track project in the region.
Subsea System Architecture
The MA D6 field is in the KG D6 Block 60 km from the east coast of India and is exposed to the eastern monsoon from April until September and to cyclones in the following months. This limits the safe and efficient operations of offshore construction vessels to a window extending from December to April.
The occurrence of cyclones led the operator to select a floating production, storage, and offloading (FPSO) vessel equipped with a disconnectable turret buoy that required a riser system designed for both connected- and disconnected-turret-buoy situations. The limited working window caused the project installation to be split into two phases: one before the monsoon season of 2008 to allow first oil on arrival of the FPSO and the second one the following year for the full production system. However, the engineering design of the whole riser system was needed at the early stage of the project to address all the interferences between the various risers during installation and operations and to define all the riser equipment in a pliant-wave configuration (Fig. 1), such as buoyancy modules, riser-anchoring piles, and tethers and clamps.
The field production system is based on the production of six wells through a production manifold, the injection of part of the produced gas into the reservoir by a satellite well, and the export of the gas to the future KG D6 gas-development field though a gas-export manifold (GEM).
The four 8-in.-inside-diameter (ID) flexible production risers connect the FPSO to the production manifold, the four 8-in.-ID gas-export flexible risers connect the FPSO to the GEM, and the gas-injection well is connected directly to the FPSO with a 6-in.-ID flexible riser/flowline. Each subsea tree is linked to the production manifold with 6-in.-ID flexible flowlines/jumpers, and control of all the subsea structures is achieved by a dynamic-umbilical connection between the FPSO and the production manifold and with static umbilical jumpers connecting the production manifold to the seven subsea trees and the GEM.
Presalt Santos Basin - Extended Well Test and Production Pilot in the Tupi Area: The Planning Phase
Authors: Denney Dennis 
Published: February 2015

This article, written by Senior Technology Editor Dennis Denney, contains highlights of paper OTC 19886, ’Presalt Santos Basin - Extended Well Test and Production Pilot in the Tupi Area: The Planning Phase,’ by Celia M.F. Nakano, Antonio C.C. Pinto, SPE, Jose L. Marcusso, and Kazuioshi Minami, SPE, Petrobras, prepared for the 2009 Offshore Technology Conference, Houston, 4-7 May.
Petrobras is assessing the potential of the Santos basin presalt reservoirs offshore Brazil. Three integrated ultrafast-track projects were planned to start production of the giant presalt reservoirs in an area known as Tupi. The objective of the three projects is to obtain relevant reservoir and production data to support the design phase of the remaining production units of the full-field development. The main technical challenges addressed include drilling complex wells, use of intelligent completions, qualifying ultradeepwater risers, establishing flow assurance through long subsea flowlines, and CO2 capture and sequestration.
Introduction
The Tupi area is in the central portion of the Santos basin, approximately 290 km offshore Rio de Janeiro State, at water depths of approximately 2200 m. The first well drilled in the block was Well RJS-628, completed in August 2006. The well was designed to test the carbonate section of an Aptian reservoir. It found a primary hydrocarbon-bearing reservoir in carbonate having microbial origin, named the SAG reservoir. A secondary microbialite reservoir, named the RIFT reservoir, also was found. Both reservoirs are below a thick regional layer of salt that occurs in this portion of the basin. Therefore, these reservoirs were classified as presalt reservoirs. The well was tested and produced after an acid stimulation. The choke-constrained production rates were 378 m3/d of 28°API crude oil with a gas/oil ratio (GOR) of approximately 220 m3/m3.
To verify the continuity of the SAG reservoir to the south, Extension Well 3-RJS-646 was drilled in July 2007, 10 km from the wildcat. The well, in the Tupi Sul area, confirmed expectations of the SAG and RIFT carbonate oil reservoirs, and reservoir characteristics were better than those of the previous well. Another oil-bearing carbonate reservoir, the Coquina reservoir, also was found. The well tested a choked rate of 445 m3/d of 27°API oil from the SAG reservoir with a GOR of 230 m3/m3. Because of logistics constraints, the deeper reservoirs could not be tested. The reservoir area was covered completely by 3D-seismic data. High-resolution seismic is being acquired in the Tupi area.
Technology Focus: Offshore Facilities (February 2011)
Authors: Ball Ian G. 
Published: February 2015

Technology Focus
Our industry continues to make great progress in creating and qualifying new technical solutions to meet the need for cost-effective offshore oil-/gas-production facilities in evermore-challenging environments. In last year’s Offshore Facilities Focus, we reviewed some of the more-prominent recent examples, and in this edition we cover some further updates on progress. There is, however, a particular theme running through these latest examples, which are perhaps worthy of some special attention.
The E&P industry is renowned for its ability to generate impressive technical solutions for just about any well-defined offshore challenge it may face. In my experience, it has been less able to demonstrate a similar global consistency across cultures in the manner in which the supplier and the client go about achieving the potential of the technology in practice.
In one recent firsthand exposure, there even appeared to be a deliberate mind-set of challenge and contractual standoff from the outset between the two parties. The intended aim was to bring about rapid execution at lowest possible cost. It is questionable whether this approach ever can be sustainable beyond the particular project in question, and whether either party’s best interests can thereby be served in practice.
What shines through in the examples covered in the following pages is how a purposefully collaborative approach can make a positive difference to the benefits for both parties. These benefits often can be enhanced further by establishing a broader constructive and collaborative framework with a wider group of stakeholders that typically can include installation contractors and classification/certification agencies.
The success of individual-project collaborations leads to a sustainable contracting environment into the future. Also, it can, in some cases, lead to global frame agreements, which can enable both parties to harvest expanded economic and schedule benefits from building on the culture of mutual respect and aligned objectives. I hope you enjoy these case studies as much as I have.
Offshore Facilities additional reading available at OnePetro: www.onepetro.org.
OTC 20762 “Demonstrating the Feasibility of Steel Catenary Risers From a Cylindrical FPSO in Harsh Deepwater Locations” by Jan V. Aarsnes, Sevan Marine ASA, et al.
OTC 20506 “Deepwater-Pipeline and -Riser Installation by the Reel-Lay Method” by S.N. Smith, Subsea 7, et al.
OTC 21024 “Top-Tensioned-Riser Systems for a New Floater Type” by David L. Garrett, Stress Engineering Services, et al.
New Reserves and Resources Guidelines Document Available
Authors: Purewal Satinder 
Published: February 2015

Management
In November, the SPE Oil and Gas Reserves Committee (OGRC) published Guidelines for the Application of the Petroleum Resources Management System (PRMS). The guidelines, available at http://www.spe.org/industry/docs/PRMS_Guidelines_Nov2011.pdf, provide information and examples on the use of PRMS in the classification of oil and gas reserves and resources.
The new guidelines replace the 2001 Guidelines for the Evaluation of Petroleum Reserves and Resources. New chapters include “Estimation of Petroleum Resources Using Deterministic Procedures” and “Unconventional Resources.” Other chapters were updated and expanded to reflect current technology and enhanced with examples. The intent of the guidelines is not to provide a comprehensive document that covers all aspects of reserves calculations, but to serve as a useful reference tool for reservoir engineering and reserves evaluation professionals around the world.
SPE has been at the forefront in developing common standards for petroleum resource definitions to provide consistency, transparency, and reliability to benefit stakeholders involved in international finance, regulation, and reporting. A milestone in standardization was achieved in 1997 when SPE and the World Petroleum Council (WPC) approved the “Petroleum Reserves Definitions.” Since then, SPE has continuously updated the definitions. In 2007, SPE, WPC, the American Association of Petroleum Geologists (AAPG), and the Society of Petroleum Evaluation Engineers (SPEE) approved the Petroleum Resources Management System, globally known as PRMS. The Society of Exploration Geophysicists (SEG) subsequently endorsed PRMS.
PRMS has been acknowledged as the oil and gas industry standard for reference and was used by the US Securities and Exchange Commission as a guide for its updated rules, “Modernization of Oil and Gas Reporting,” published in 2008.
SPE recognized that new applications guidelines were required for the PRMS. The SPE Oil and Gas Reserves Committee formed an Applications Guidelines Document Subcommittee in April 2007 to undertake this task. I was honored to be asked to chair the subcommittee. The original 2001 guidelines document was the starting point for this work. The goal was to have an inclusive process where the industry was involved and all stakeholder input was considered fairly by experts.
Drillpipe-Dynamics Measurements - Insight Into Drillstring Dysfunctions
Authors: Denney Dennis 
Published: February 2015

This article, written by Senior Technology Editor Dennis Denney, contains highlights of paper SPE 145910, ’Drillpipe-Dynamics Measurements Provide Valuable Insight Into Drillstring Dysfunctions,’ by Constantijn Raap, SPE, Andrew D. Craig, SPE, and Ryan Graham, SPE, NOV, prepared for the 2011 SPE Annual Technical Conference and Exhibition, Denver, 30 October-2 November. The paper has not been peer reviewed.
The drilling industry has become increasingly interested in drilling dynamics and in vibration as a cause of reduced drilling performance and downhole-tool and drillstring failures. Vibration data have been captured with measurement-while-drilling (MWD) tools in the lower bottomhole assembly (BHA). However, this approach is not always sufficient to understand the drillstring dynamics of more-complex applications. High-frequency vibration data were recorded at several strategic points within the drillstring by use of downhole dynamics recorders (DDRs). These data provided new insights into the dynamic behavior of drillstrings in high-angle wells.
Introduction
Drillstring vibration is a limiting factor when drilling horizontal and extended-reach wells. While rotating, long sections of drillstring are positioned on the low side of the hole. If sufficient friction exists in the wellbore while being rotated at constant speed from surface, the string will decelerate angularly, followed by a rapid increase in rotational speed. This torsional vibration, often referred to as stick/slip, generally increases with a combination of lower rotary speeds and higher surface weights. Typical consequences of torsional vibration may include overtorqued connections, torsional fatigue, and high wear of downhole-tool components, and it has been identified as the leading cause of damage to polycrystalline-diamond-compact bits.
Rotating the string faster than a system specific threshold or at increased compressive load causes the string to move up and down the wellbore. This snaking motion is characterized by movement in the lateral plane, which causes lateral shocks each time the BHA or pipe contacts the wellbore. Field experience indicates that higher rotary speeds generally lead to increased levels of lateral vibration. Severe lateral vibration, such as whirl, can have detrimental consequences, such as downhole-tool failure, impact damage to drill bits, and drillstring twistoffs. Both torsional and lateral vibration lead to reduced penetration rates and numerous unwanted BHA or bit trips.
Another limiting factor encountered when drilling high-angle wells is the torque required to rotate the drillstring. High drillstring torque can limit the well stepout if the maximum available top-drive- or drillpipe-torque limit is exceed-ed. It is common that both high torque and vibration occur simultaneously.