bluuebunny/crossref_metadata_2025_split huggingface dataset:
Overview: HP/HT Challenges (March 2005)
Authors: MacAndrew Robert 
Published: February 2015

It is quite a thought when those of us who have been in this industry for more years than we perhaps care to count take a few moments to look back and reflect on the progress made in drilling and completing high-pressure/high-temperature (HP/HT) wells over the years. It is easy to for-get that oil-based mud was developed to answer the problem of high-temperature wells. It was only when oil-based mud’s inhibitive properties MacAndrew in reactive clays were recognized that it became common in more-prosaic “normal” wells where the time savings made the higher cost of the oil-based mud economical and, in many places, changed the drilling of wells out of all recognition when compared with drilling with water-based mud. I am sure there are some reading this who can remember the original diesel-based muds. Just as in the case of mud, the demands of high operating pressures and temperatures drove our industry to develop higher specifications and manufacturing standards for equipment that have provided benefit to the rest of the industry.
Now, we are pushing to drill HP/HT wells in water depths that push boundaries ever further. Today, we are drilling HP/HT wells for which, aside from drilling the HP/HT section, drilling the non-HP/HT section often is a significant challenge in itself. In the Gulf of Mexico deep-gas shelf play, well depths of more than 30,000 ft, pore-pressure regimes of 30,000 psi, and bottomhole temperatures of 500°F are actively contemplated. These sorts of plays are stretching technology as much as, if not more than, the first HP/HT wells did. Our industry is taking on the challenge of not only drilling these new “super” wells, but also finding the materials to complete them and produce the hydrocarbons. The oil and gas industry may be seen by many as a mature one; but taking on the new challenges of HP/HT wells makes it just as exciting as any of the newer, more-fashionable industries.
There is life in the old dog yet!
Additional HP/HT Challenges Technical Papers
Available at the SPE eLibrary: www.spe.org
SPE 87094 - Numerical Models Help Analyze Lost-Circulation/Flow Events and Frac-Gradient Increase to Control an HP/HT Well in the Eastern Mediterranean Sea
SPE 92218 - Jade North Sea HP/HT Development: Innovative Well Design Generates Best-In-Class Performance
SPE 92003 - Reservoir Simulations of Gel Treatments To Control Water Production Improve the Sweep Efficiency and Conformance Factor in Eastern Venezuelan HP/HT Fractured Reservoirs
Overview: HP/HT Challenges (March 2007)
Authors: MacAndrew Robert 
Published: February 2015

It has been quite an enlightening experience reviewing potential papers for this issue of JPT. Over time, there has been a steady geographic spread of high-pressure/high-temperature (HP/HT) activity, which is reflected in the papers the Society is publishing. Papers are being presented at conferences around the world. The geographic area has expanded, issues being addressed at these conferences are widening, and our industry is addressing the challenges being presented by drilling, completing, and producing from HP/HT reservoirs. A body of experience in operating HP/HT developments is being built up, and through SPE, these experiences are being disseminated throughout the industry.
We now have HP/HT wells being split into three categories based on the temperature and pressure envelopes, namely Tier 1 (HP/HT), Tier 2 (extreme HP/HT), and Tier 3 (ultra-HP/HT). Ultra-HP/HT wells, with temperature higher than 400°F and pressure greater than 20,000 psi, are being planned, and this work is highlighting the current limitations in available technology in many areas. At the upper limits of Tier-2 wells (i.e., pressure of 20,000 psi and temperature of 400°F), we generally are at the limits of current technology, and there are such serious technological gaps that completing these wells currently is beyond our capabilities. All is not gloom and doom; the service sector is seriously investigating future equipment developments to meet the demands of these wells.
Some service companies are working under their own initiative, and at least one commercial joint-industry research and testing venture is being proposed to the industry. The big question is: Can the industry apply the necessary resources of people and money in time to prevent a stalling of ultra-HP/HT developments?
HP/HT Challenges additional reading available at the SPE eLibrary: www.spe.org
SPE 99968 "New Downhole Electromechanical-Service-Tool Advancements Provide Increased Integrity in HP/HT Environments" by J. Foster, Halliburton Energy Services Group, et al.
SPE 98869 "Finite-Element Analysis Couples Casing and Cement Designs for HP/HT Wells in East Texas" by J. Heathman, SPE, Halliburton, et al.
SPE 98896 "Effects of Long-Term Exposure to Ultrahigh Temperature on the Mechanical Parameters of Cement" by D. Stiles, SPE, ExxonMobil Development Co.
Managing the Tradeoffs: Similarities Between Managing New Product Development and a Well Drilling/Completion Project
Authors: Shaw B.S. , Morris T.G. 
Published: February 2015

As stated by Smith and Reinertsen in Developing Products in Half the Time, “managing the tradeoffs” should be a primary consideration when planning and executing a development project. Managing the tradeoffs means being aware of four major project objectives inherent in all development projects and actively managing the six potential interactions between these four objectives. This technique provides the project execution team with tools that, when applied consistently, ensure optimized project/product delivery within a win-win atmosphere. This technique can work as well for a drilling/completion project as it does for new product development projects.

Cross-Functional Teams
The concept of establishing co-located, cross-functional project execution teams for both new product development and for oil- and gasfield development is well established. These teams are most effective when they are:
- Led by a competent and committed project manager with full management support.
- Empowered to make value-added decisions on behalf of the project and the company.
- Aligned with a common set of goals and rewards.
- Allowed to define their own work processes and encouraged to build team spirit.
- Held accountable to clear and realistic targets.
- Provided with the best training, tools, and technical support available.
For developments that rely on suppliers for delivery of critical equipment, services, and technology, an important element of success is to include a technical representative from each major supplier. Additionally, a well-constructed development process, such as a stages-and-gates (or “toll-gate”) process, helps the team break the work into manageable pieces and to focus on the deliverables that will lead to success at the next step of the project.
Technology Focus: Offshore Drilling and Completion (April 2008)
Authors: Jousseaume Jean-Louis 
Published: February 2015

Technology Focus
I do not yet consider myself an old-timer. However, I remember when I started studying petroleum engineering; our teacher was telling us that drilling was a technology that had not progressed in years, not since its last revolution—the introduction of rotary drilling. The word "revolution" here definitely seems the right one.
Since those days, we have seen the introduction of new technologies, such as measurement while drilling, steerable systems, top drives, more-reliable dynamic-positioning systems, dual handling, smart completions, new equipment, new chemicals, new metallurgy, and an exhaustive list of others. These advances enabled success of wells that were increasingly difficult, and we now are drilling horizontally (again, I remember: "It is impossible to drill horizontally, because it is impossible to transmit weight on bit horizontally") and underbalanced, we are drilling high-pressure/high-temperature (and soon very-high-pressure/very-high-temperature) reservoirs and in deep and ultradeep waters, and we are drilling slim or ultraslim wellbores, multilateral and extended-reach wellbores, and combinations of these. Future wellbores will be even more exotic.
We complete wells with smart technology or sophisticated multilateral connections, produce gas from tight or ultratight sands, and heat silts in-situ to produce heavy bitumen. Simultaneously, we are making tremendous progress to protect people from incidents and diseases and our environment from unbearable or irreversible damages, especially when using nonaqueous-based mud.
Again, this list of recent advances is not complete, but it gives the strong feeling that all of us are engineers dealing with a moving and expanding technology. Actually, it gives me the strong belief that we will overcome new challenges and that, peak oil or not (whenever it may happen), there still is a lot to engineer, a lot to invent, and a lot to progress to move the limits of feasibility in drilling and well engineering further and further.
Offshore Drilling and Completion additional reading available at the SPE eLibrary: www.spe.org
SPE 105212 • "Deployment of a Riserless Mud-Recovery System Offshore Sakhalin Island" by J.D. Brown, CJSC Elvary Neftegaz, et al.
SPE 110359 • "Subsea Slimhole Completions in Deepwater Gulf of Mexico: Case Histories" by J.R. Sanford, Eni Petroleum, et al.
Additional reading available at the OTC Library: www.otcnet.org
OTC 19077 • "First Jackup Drilling Operation on Grand Banks of Newfoundland—Lessons Learned" by G.C. Bagnell, Rowan Companies
OTC 18496 • "2-Million-lbm Slip-Based Landing-String System Pushes the Limit of Deepwater Casing Running" by James N. Brock, Grant Prideco, et al.
Gumusut-Kakap Project: Geohazard Characterization and Effect on Field Development
Authors: Bybee Karen 
Published: February 2015

This article, written by Assistant Technology Editor Karen Bybee, contains highlights of paper IPTC 12554, "Gumusut-Kakap Project: Geohazard Characterisation and Impact on Field- Development Plans," by C. Hadley, D. Peters, and A. Vaughan, SPE, Shell International E&P, and D. Bean, Sarawak Shell Sdn. Bhd., originally prepared for the 2008 International Petroleum Technology Conference, Kuala Lumpur, 3-5 December. The paper has not been peer reviewed.
Shell and venture partners encountered numerous seafloor and near-seafloor geohazards at the deepwater Gumusut-Kakap field on the continental slope offshore Malaysia. Early identification of the geohazards, by interpretation of exploration 3D-seismic data and evaluation of discovery and appraisal-well logs, provided the impetus necessary to undertake an extensive data-acquisition program to determine the extent of the hazards and the mitigation needed for a successful development.

Introduction
The Gumusut-Kakap field in the Malaysian deepwater province offshore northwest Borneo was discovered in 2003 with the drilling of the Gumusut-1B well. The field is 120 km offshore, in the southern portion of Sabah Block J and Block K. Four appraisal wells, Gumusut-2 and Gumusut-3 in Block J and Kakap-1 and Kakap-2 in Block K, were drilled during 2004–05.
The seafloor slopes regionally to the southwest, with a gradient of approximately 5°, and water depths within the development area vary from 900 to 1200 m. Seafloor and near-seafloor sediments are hemipelagic, interbedded with turbidites and mass-transport deposits (MTDs). Exploration 3D-seismic data and data from the discovery and appraisal wells were interpreted in 2005 to identify geohazards that could influence field-development plans and to screen potential surface well locations.
The seafloor extraction from the 3D-seismic data set revealed a variable seafloor topography. The most prominent topographic features are a series of upper-slope canyons, which are interpreted to be the seafloor expression of buried mass-transport complexes and a steep-sided seafloor bulge. The bulge rises 120 to 150 m above the surrounding seafloor and is approximately 8 km wide. The bulge is the surface expression of one of a series of deep-seated anticlines, which are common in the region. Both flanks of the bulge have been eroded by downslope mass failures. Appraisal wells Gumusut-2, Kakap-1, and Kakap-2 were drilled on the bulge.
Anomalies in the subsurface data included a bottom-simulating reflector (BSR) between 150 and 180 m below the seafloor, which underlies the downdip portion of the bulge and coincides with an extensive seismic wipeout zone.
Shared Vision (May 2005)
Authors: Paccaloni Giovanni 
Published: February 2015

SPE is a very inclusive organization.
We embrace diversity as a core value that stimulates learning, enhances creativity and promotes excellence. We gain strength and vitality from the wide range of experiences and perspectives that our members bring to SPE. From Asia Pacific to Europe, from the Middle East to North and South America, I have met SPE members of every age group, career level, cultural background and technical discipline. SPE has earned a reputation as a neutral body that transcends geopolitical issues by focusing on knowledge exchange that considers all viewpoints, and by treating members fairly and equitably. Our members know that they can advance to any level within SPE because we value individual differences. The makeup of SPE’s board, committees, task forces and teams reflects the diversity of our membership.
Our current membership demographics clearly reveal our increasingly global makeup, and an amazing array of job types, job levels and company affiliations. Just five years ago, 40% of our members lived outside North America. Now, more than 50% of our members are geographically dispersed in 108 countries.
The globalization of SPE becomes even more apparent when you look at membership growth over the last five years: Middle East, +33%; Africa, +75%; Asia Pacific, +26%; South America, +21%. Although North Sea regional membership remains stable, membership in South Central and Eastern Europe is up 21%. North American membership increased 2%in the last five years. New sections have opened this year in Switzerland, Argentina and India, underscoring our growth on three continents.
Our diversity extends beyond geography into job focus. SPE is not just for petroleum engineers—SPE is for all professionals who work in the upstream energy industry. While 44% of our members report that they are engineers in various disciplines, 20% describe themselves as managers and 15% are executives. Our members are also educators, consultants, technicians and geoscientists.
The spectrum of professions and expertise within SPE becomes even more fascinating when we look at the degrees our members hold. SPE has defined six technical disciplines that reflect the wide range of our members’ specialties: Drilling and Completions; Health, Safety and Environment; Facilities and Construction; Management and Information; Production and Operations; and Reservoir Description and Dynamics. In addition to the expected engineering and geoscience degrees, we have members who are medical doctors and nurses (in Health, Safety and Environment); members who hold law degrees, PhDs in a range of disciplines and MBAs (in Management and Information); and those with less common degrees like food chemistry or industrial economy who have found their way into the industry. We even have master mariners.
Guest Editorial: Safe Drinking Water: A Case for Service
Authors: Koerner Roy H. 
Published: February 2015

My good friend Lyn Arscott, a former SPE President and an SPE Foundation Trustee, introduced the subject of engineer volunteerism last month. Our 2007 SPE President, Abdul-Jaleel Al-Khalifa, encouraged us to write these guest editorials because we have before us a magnificent opportunity to help change the world for the better. We can help provide safe drinking water to millions around the globe and help save lives in a world where waterborne diseases kill a child every 15 seconds.
Why do people serve? We empathize with others in distress and have since birth. Psychological experiments prove this through the observations of newborn babies in nurseries. When one baby cries out in suffering, it results in a cacophony of wailing infants. Noise is not the causal factor. A recording of a baby's cry, played back, does not result in more crying. The baby recognizes its own cry and also empathizes with another human in distress. Why? A logical reason is found in the evolutionary study of early humans. Ancestral Homo sapiens survived by relying on and cooperating with others. Even those Neanderthals who suffered severe injuries, such as loss of limbs, had to be nurtured.
Why should we serve? Psychologists have demonstrated that helping others less fortunate in a personal, hands-on way results in a sense of well-being and improves our self-image by showing us that we lead a purposeful life. Thus, we enrich our lives through service. Serving others helps us succeed by improving our relationships with family, friends, acquaintances, work associates, and many other people.
Managers who are sensitive to their employees' needs and act on them are more successful. And at least two comprehensive studies prove that companies that have written ethical value statements and operate by those standards make more money and provide higher returns to investors, on average, than other companies.
A recent article in Business Week (29 January 2007, page 50) illustrates the point that companies that do good things for their communities often do well financially. Individuals also prosper by doing good things for their fellow human beings. Engineers serve by solving problems. For example, engineers at Colorado State University developed a cook stove with a thermoelectric generator that provides sufficient electricity to power a room light, a small TV, or a radio for hours. This connects many people to the outside world for the first time. Engineers Without Borders provides technical assistance to areas that have needs and has worked to bring safe drinking water to developing areas. Another engineering marvel is the "Lifestraw," a device that uses filters and other components to purify water as someone sucks water through a tube. It provides about a year of safe water from surface sources. SPE members have many natural and learned skills that could benefit others around the world.
Invert-Fluid Flocculation: A Method for Recycling Drilling Fluid
Authors: JPT staff _ 
Published: February 2015

A new technology is now in use to increase the efficiency of traditional solids-control equipment in removing colloidal fines and water from invert drilling fluids. This method makes it possible to extend fluid lifespan and recover and reuse valuable components. Colloidal fines—particles measuring less than 2 µm equivalent spherical diameter—are typically difficult to remove through the exclusive use of mechanical devices relying on screening or gravity. Through the application of chemistry and equipment packages, these colloidal solids now can be removed from systems with a hydrocarbon-continuous phase through a process of flocculation, which aggregates these fines to facilitate their removal. The use of this process results in a high-performance fluid with lower density, increased oil content, and no colloidal solids. The benefits go beyond those associated with traditional treatment methods and include the alternative provided to the disposal of unusable stock.
The invert-fluid flocculation technology, called Reclaim, was introduced recently by M-I Swaco. Invert drilling fluids are water-in-oil emulsions containing a hydrocarbon-continuous phase with an emulsified internal aqueous "brine" phase in addition to clays, weighting agents, and other additives (Darley and Gray 1988). These fluids serve many functions during drilling, one of which is to remove excavated rock, or "drill cuttings," from the borehole. These solids are incorporated continuously into the mud, with solids-control equipment employed at the rigsite to remove them and return the drilling fluid to the active system in a usable condition. Typical equipment, such as shakers and centrifuges, remove solids greater than 5 to 7 µm (ASME 2005). However, as drilling fluids are used to drill multiple holes, fine particles can build up and ultimately create problems for efficient drilling. Typically, the drilling fluid is diluted and reformulated to reduce the concentration of these fine solids and return the fluid to acceptable physical properties. This is often costly and also increases the volume of drilling fluid, leading to problems of storage, transport, and disposal. In severe cases, in which dilution is uneconomic, the drilling fluid will be disposed of as waste and fresh fluid mixed. This involves significant cost and environmental impact.
The new technology uses polymeric inverse emulsions and surfactants coupled with defined-shear and mixing systems to flocculate fine solids in invert drilling fluids, enabling them to be removed by use of standard oilfield centrifuges. The result is the reclamation of the hydrocarbon component with no fine-contaminant solids, and this reclaimed hydrocarbon stream can be used as base fluid for new drilling formulations. This significantly benefits the processes of fluids recycling and inventory control, reduces disposal volume, and improves drilling performance.
Human Factors in Control-Center Design
Authors: Denney Dennis 
Published: February 2015

This article, written by Technology Editor Dennis Denney, contains highlights of paper IPTC 11762, "Improvement of Human Factors in Control-Center Design - Experiences Using ISO 11064 in The Norwegian Petroleum Industry and Suggestions for Improvements," by Andreas Lumbe Aas, Norges Teknisk- Naturvitenskapelige Universitet, Dept. of Computer Science, and Stig Ole Johnsen, Sintef Technology and Society, prepared for the 2007 International Petroleum Technology Conference, Dubai, 4-6 December. The paper has not been peer reviewed.
Managing human factors (HFs) in the design of control centers (CCs) has become increasingly important in large-scale petroleum projects because of the effects on safety and on efficient operations. Integrated operations (IOs) introduce new ways of working, allowing virtual teams, but raise new risk-management issues. In 2006, 22 persons, representing different sectors and professions in the industry, were asked about their experiences with International Organization for Standardization (ISO) 11064, the standard guide to "ergonomic design of control centers" for handling HFs during design of CCs. This paper summarizes experiences applying ISO 11064 in Norwegian petroleum projects and suggests areas for improvements.

Introduction
This study mapped experiences in applying ISO 11064 to CC design in full-scale industrial projects [e.g., construction of new offshore installations (oil platforms); floating production, storage, and offloading vessels; and onshore process installations] as well as major CC modifications of the same.
Fig. 1 shows the ergonomic-design process for CCs in ISO 11064. This process has five phases, A through E, that perform iteratively. ISO 11064 consists of seven parts, of which Part 5 is still in draft. This paper focuses on Part 1, principles for the design of CCs, because this was the part most commonly used among interviewees. Several interviewees pointed out that Part 3, control-room layout, and Part 7, principles for the evaluation of CCs, also were important.
ISO 11064 is a normative reference in the regulations relating to design and outfitting of facilities as published by the Petroleum Safety Authority Norway (PSA), the Norwegian Pollution Control Authority, and the Norwegian Social and Health Directorate. ISO 11064 is not designed specifically for IOs, but the principles of the standard can be used for IOs.
The systematic consideration of human error in systems designs can lead to improved safety, even improved productivity in many cases. To allow for efficient design of safety-critical systems, it is important to have flexible safety standards that provide a good cost/benefit ratio and contribute to the design of safer systems. Therefore, a goal-based approach is discussed.