bluuebunny/crossref_metadata_2025_split huggingface dataset:
Distribusi Ukuran Spasial-Temporal dan Berdasarkan Tingkat Kematangan Gonad Rajungan (Portunus pelagicus Linnaeus 1758) di Teluk Lasongko, Buton Tengah, Sulawesi Tenggara
Authors: Hamid Abdul , Wardiatno Yusli , Batu Djamar T.F. Lumban , Riani Etty 
Published: January 2017

The aim of the study was to reveal spatial-temporal distribution of the blue swimming crab(Portunus pelagicus Linnaeus 1758) in terms of size and gonad maturity stage of both male andfemale. Sampling of crab was conducted with a gill net from April 2013 until March 2014 inLasongko Bay. Of the whole population the mean size of male was smaller than that of females.Spatially smaller crabs (juveniles and young ones) inhabited mostly inner side of the bay, whilemedium size crabs occurred in the middle part of the bay. Big crabs were mostly found in theouter side of the bay. In terms of time, big sise of male and female crabs were collected inperiod of October to November and September to March, respectively. Small size of male andfemale occurred in February to September and in April, respectively. Related to gonad maturity,the sizes of both sexes with mature stages were variable. Ovigerous female (OF) was presencewidely in the bay, but the size of ovigerous females living in the shallow part of the bay wassmaller than those living in the deeper part. Keywords: blue swimming crab, size distribution, carapace width, spatial-temporal, gonadmaturity
Status Pengelolaan Sumberdaya Ikan Demersal Sekitar Pantai di Kabupaten Indramayu, Jawa Barat
Authors: Yulianto Gatot , Suwardi Kadarwan , Adrianto Luky , Machfud Machfud 
Published: January 2017

The status of fish resources in management fisheries context is important to be known for settingresources policy in order to ensure continuity of fish stock and harvest. Estimating the level ofsustainable catches and economic rent by using surplus production approach and Gordon-Schaeferbioeconomic analysis then comparing the actual condition, it will point to level of resource exploitationand level of resource degradation. The management of demersal fish around the beach in IndramayuRegency which is characterized by open access resource indicate the status of the fish resource in astate of overfishing and degraded. Therefore, it is important for designing fisheries managementpolicy by regulating the amount of fishing effort.Keywords: demersal fish, bioeconomic analysis, overfishing, degradation
Managing Project Uncertainty: The Delphi Method
Authors: Saldin Lakshan , Healey Matthew , Parker Kate 
Published: January 2017

Management
Decision making in uncertain environments is key to the successful delivery of oil and gas projects. By definition, however, uncertainty is ambiguous and unpredictable.
Uncertainty does not necessarily imply risk; the two are separate concepts. Economist Frank Knight made a clear distinction between the two as far back as 1921. Risk can be measured and quantified and is well suited to the analytical techniques used in project risk management; uncertainty defies quantitative expression. Items with the quality of uncertainty often surface during risk-assessment exercises but tend to be categorized as “issues” and are neither captured nor addressed by traditional risk-management processes.
Donald Rumsfeld’s infamous quote highlights the difficulty of articulating uncertainty. However, the statement is rooted in sound cognitive and sociological theory and makes an important point about the perils of taking our individual and shared perceptions for reality. The philosopher Slavoj Žižek (2006) suggests that there may also be a fourth category of “unknown knowns”—those things that we intentionally refuse to acknowledge due to, for example, the social stigma around dissent. While we may feel confident dealing with “known knowns” and “known unknowns,” how can we hope to discover the “unknown unknowns” and uncover the “unknown knowns”?
These problems can be effectively addressed using a Delphi-based workshop methodology. The process presented in this article discusses how to work collaboratively to develop a common understanding of a project and achieve alignment on issues and uncertainties. This allows managers to gain a better understanding of the critical uncertainties running through the project and implement appropriate strategies.
Delphi Methods
Delphi is a structured communication technique that was developed as part of the United States’ response to global uncertainty during the Cold War. Since then, the process has been used across many different industries worldwide (Linstone and Turoff 2002). Delphi-based methods are able to draw out the tacit knowledge held by project members and assess it in a structured manner.
An Improved Model for Predicting Hydraulic-Fracture-Height Migration
Authors: Carpenter Chris 
Published: January 2017

This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 173335, “An Improved Equilibrium-Height Model for Predicting Hydraulic- Fracture-Height Migration in Multilayer Formations,” by Songxia Liu, SPE, and Peter P. Valko, SPE, Texas A&M University, prepared for the 2015 SPE Hydraulic Fracturing Technology Conference, The Woodlands, Texas, USA, 3–5 February. The paper has not been peer reviewed.
While many factors may influence fracture-height evolution in multilayer formations, the consensus is that the so-called “equilibrium height belonging to a certain treating pressure” provides an upper limit, at least for nonnaturally fractured media. The authors have revisited the “equilibrium-height problem,” and their theoretical and numerical investigations led to a new model that fully characterizes height evolution amid various formation properties.
Introduction
Solutions for the equilibrium-height problem have been known since the 1970s, and several models have been developed for calculating hydraulic-fracture height. However, because of the complexity of the algebra involved, the equations used in these early models were overly simplified and gave unreliable results.
The authors developed an improved, mathematically rigorous model that, for the first time, solves the equilibrium height under various formation-property conditions and fluid properties. The authors started from the definition of fracture toughness, incorporated the effects of hydrostatic pressure, and considered nonsymmetric variations of layered formation properties. The model was applied to the classic three-layer problem and then extended up to six layers.
With the new model, the effects of fracture toughness, in-situ stress, fluid density, and their interactive effects on fracture-height growth were investigated. The full height profile with very large top and bottom formation thicknesses showed the ultimate trend of fracture-height migration. Two three-layer pseudo problems were constructed to create an outer and inner height envelope for any multilayer-formation problem, to assess the potential effects of reservoir-parameter uncertainties on height profile. The occurrence of a second solution pair and its analytical solutions were presented, to avoid misleading results in the 3D models.
OTC Asia Highlights Industry Achievements
Authors: Whitfield Stephen , Wilson Adam 
Published: January 2017

Conference Review
More than 15,000 energy professionals representing 2,500 organizations and 60 countries gathered from 21 to 25 March in Kuala Lumpur for the Offshore Technology Conference (OTC) Asia. With the theme “Excellence in Asia,” the conference builds upon the highly successful inaugural OTC Asia held in Kuala Lumpur in 2014.
The conference reflects Asia’s position as a global provider of exploration and production (E&P) technology, in which cultural and geographical diversity foster collaboration and innovation.
Opening Session
The prime minister of Malaysia, Dato’ Sri Mohd Najib bin Tun Abdul Razak, gave the keynote address during the opening ceremony. Speaking about Malaysia’s role in both the Asian oil and gas industry and the global economic market, the prime minister said the country was in position to further develop a diverse economy and become a central figure in an industry undergoing volatile change.
Najib said the industry must have a realistic perspective on its immediate future. He said crude oil prices will likely remain low because of several external factors, including the continuing supply of shale oil in the US, Iran’s re-entry into the oil and gas market, and the intransigence of the Organization of the Petroleum Exporting Countries in cutting production to limit supply.
Despite this immediate outlook, Najib said the Malaysian economy is in position to withstand the aftereffects of the low-price environment in large part because of his government’s push for greater economic liberalization during his 7 years in office. The prime minister cited his MYR- 67-billion stimulus package in 2009 as a significant driver of economic growth.
“Since I came in office, the [Malaysian] government has been making the necessary steps to have in place important measures to ensure that our economy remains resilient, to buffer our economy so as to weather any significant systemic shocks from domestic as well as external sources,” he said.
Methodology Evaluates Artificial-Lift Requirements Amid High Uncertainty
Authors: Wilson Adam 
Published: January 2017

This article, written by Special Publications Editor Adam Wilson, contains highlights of paper SPE 177436, “A Systematic, Integrated Approach To Evaluate Artificial-Lift Requirements While Dealing With High Uncertainty,” by S. Caicedo, C. Montoya, J. Abboud, and S. Tiar, Abu Dhabi Company for Onshore Petroleum Operations, prepared for the 2015 Abu Dhabi International Petroleum Exhibition and Conference, Abu Dhabi, 9–12 November. The paper has not been peer reviewed.
When evaluating artificial-lift requirements, sometimes data present uncertainties at the initial planning stage. This is the case for a field that had 10 wells drilled but only four of them producing after 6 years, at which point operations were suspended. The high-level plan was to exploit and abandon the reservoir as soon as possible. This paper presents the integrated and structured methodology that was used to deal with the high-uncertainty conditions.
Introduction
ABC is a small field that has 10 wells, out of which only four produced from 1993 to 1999 while the remaining six were shut in after few months of production. Subsequently, the operations in ABC were suspended and the surface facilities were mothballed. Because of attractive remaining reserves along with high reservoir pressure, and considering that this field is in an urbanized area, a plan was requested that would deplete and abandon the reservoir as quickly as possible. Because of the adjusted time frame for the project, developing and planning this task required a preliminary analysis using the available data acquired during the 6 years of operation and some complementary reservoir studies. Because ABC is a complex reservoir with natural fractures and varying condensate composition, the reservoir-model uncertainties were difficult to minimize with data from only four wells and 6 years of history.
Typically, artificial-lift evaluation comes after the reservoir has a good model and a defined exploitation scheme. In this case, the selection of the artificial-lift method dealt with high data uncertainty associated with reservoir pressure, gas/oil ratio (GOR), and water-cut profiles because of the reservoir’s complexity and pressure/volume/temperature (PVT) properties. To overcome the uncertainty and advance the study concurrently with an ongoing reservoir- simulation study, the following approach was adopted:
Understand and demonstrate how uncertainty in ABC affects artificial-lift selection.
Perform a preliminary artificial-lift- method screening for a matrix covering a range of reservoir pressures, GORs, water cuts, and wellhead pressures in order to discard some methods and focus on possible solutions.
Build a matrix to determine the conditions under which the wells flow naturally and those under which artificial lift is required.
Determine the probability of the scenarios in relation to the results of reservoir-simulation work.
3D Printing in the Oil Field Kicks Into Production Mode
Authors: Jacobs Trent 
Published: January 2017

The biggest oilfield service companies in the world are using 3D printers to make metal components for a growing number of tools and equipment.
This is a significant development. It shows how far the needle has moved since these companies first embraced 3D printing more than a decade ago for the rapid prototyping of plastic models. Though the early work is being done on a small scale it gives us the first look at the future of manufacturing in this industry.
“Like any technology that evolves quite rapidly, it has tremendous potential,” said Rustom Mody, the vice president of technical excellence at Baker Hughes. “It not only reduces the cost, it accelerates the innovation process, and at the same time it gives you more functionality.”
The ability to deliver that trifecta—cheaper, quicker, better—has made the trillion-dollar oil and gas industry the fastest growing user of 3D printing according to some market analysts.
In metallic 3D printing, powderized stainless steel and other alloys are melded together with high-precision lasers. Each layer is usually built from the bottom up, hence why many of the technology’s truest advocates prefer the synonymous term additive manufacturing to describe the process of 3D printing.
Those working in this field are understandably excited about its capabilities but they are also quick to point out a number of limitations that must be addressed before production-mode 3D printing becomes a more widespread practice.
This unfinished business is one reason not a single SPE paper has been written about the topic. As companies climb the steepest part of the learning curve they tend to treat their progress as a trade secret. But the ice is beginning to thaw as more 3D printed components head out into the field.
For now those parts are small—less than a cubic foot in volume. They cannot be structural or safety-critical, and companies have had precious little time to evaluate the long-term performance of the materials for things such as corrosion or high temperatures. Additionally, there are no industry-defined standards for printed metal.
Drilling Automation Saves Rig Time and Safeguards Against Human Error
Authors: Wilson Adam 
Published: January 2017

This article, written by Special Publications Editor Adam Wilson, contains highlights of paper SPE 177825, “Breakthrough in Drilling Automation Saves Rig Time and Safeguards Against Human Error,” by Egill Abrahamsen, SPE, and Ronny Bergerud, Sekal, and Roald Kluge and Matthew King, Statoil, prepared for the 2015 Abu Dhabi International Petroleum Exhibition and Conference, Abu Dhabi, 9–12 November. The paper has not been peer reviewed.
This paper shows how automation reduces invisible lost time and allows drillers to focus on other activities while repetitive tasks are controlled by software. An automated drilling-control system using advanced modeling of well conditions in the North Sea helped the rig save up to 10% of rig time per well through safeguarding and optimizing manual operations and automating repetitive activities such as tripping, pipe filling, connections, and pump startup.
Introduction
To explain why the real-time model-based automated system deployed on the rig was capable of saving up to 10% of rig time, the following factors must be considered:
The effect that time and temperature have on drilling-fluid properties and thereby why conventional operations must be kept at a conservative level compared with automated operations tuned to current downhole conditions
The reduction of invisible lost time and the realization of faster, smoother drilling operations with fewer unplanned drilling events, obtained through shorter connection times, automated pump startups and shutdowns, automated friction tests, and active (automated) safeguards and safety triggers that assist drillers during manual operations
The human factors and team efforts to optimize operations further wherever possible
Drilling Fluid
Some of the main functions of the drilling fluid are to cool the drill bit; transport drill cuttings out of the wellbore; and maintain downhole pressures to avoid fluid influx or formation collapse, prevent fluid losses, and avoid formation fracturing.
Guest Editorial: Risk Management at NASA and Its Applicability to the Oil and Gas Industry
Authors: Kaplan David 
Published: January 2017

Guest editorial
On initial consideration, one might reasonably ask: What can the National Aeronautics and Space Administration (NASA) contribute to the oil and gas industry?
About 3 years ago, a senior principal at Deloitte Advisory’s Energy & Resources Operational Risk Group reached out to NASA to better understand the safety culture at NASA with the intent of understanding how that culture might translate to oil and gas operations. Very quickly, the conversation expanded to the realm of risk management.
Working with Deloitte, NASA came to appreciate the remarkable similarities between an offshore deepwater facility and the International Space Station. Both exist in extremely hostile environments. Both function in remote locations where movement of crew and supplies must be carefully choreographed. Both are extremely complex engineering structures where human reliability plays a critical role in mission success, and both have a deep commitment to personal and process safety.
It also should be noted that both have dedicated teams—the onboard crew and the onshore support experts—that live by the mentality that “failure is not an option” because of the consequences to life and the environment should a catastrophic mishap occur.
At NASA, we use qualitative techniques— such as fault trees, failure modes and effects analyses, hazard assessments, etc.—to understand risk based on statistics, experience, or possibilities that our engineers can anticipate. Similarly, upstream oil and gas exploration and production uses qualitative techniques—such as process safety methods, barrier analyses, bowtie charts, hazard identification, hazard and operability studies, etc.—to assess risk. At NASA, these qualitative approaches are augmented by a quantitative risk-assessment technique called probabilistic risk assessment (PRA) to uncover and mitigate low-probability sequences of events that can lead to high-consequence outcomes.
Why PRA?
The technique of PRA was developed by the nuclear power industry and initially published in mid-1975, though not widely publicized. However, the investigation of the Three Mile Island incident in 1979 revealed that the PRA had documented the sequence of low-probability events (both of hardware failures and human errors) that led to the high-consequence near-meltdown of the nuclear core. As a result, the US Nuclear Regulatory Commission has required a facility-specific PRA for every nuclear power plant in the United States.
The Reason to Expect Prolonged USD 30–60/bbl Oil
Authors: Schulz Rodney 
Published: January 2017

Management
Since 1982, the year oil prices were deregulated in the US, the import oil price to the US has averaged USD 52/bbl in 2015 dollars. It is volatile, having a monthly standard deviation of 9%, although volatility ebbs and flows. The global oil price, like the price of any commodity or security in a free and open market, incorporates all available information almost instantaneously and follows a random walk pattern.
With the above factors in mind, what can today’s oil and gas professional expect for the near- to mid-term oil price? Although the answer may not be welcome, a fairly stable set of conditions coalesce to make a strong reason to expect the oil price to generally range between USD 30/bbl and USD 60/bbl for the foreseeable future.
The Global Macro Situation
To understand the situation, it is helpful to first look at two global macro factors. First, the world consumes approximately 90 million bbl of oil every day. And second, three countries, Saudi Arabia, Russia, and the US, are the largest suppliers, with each producing between 9 and 11 million BOPD (Table 1). Beyond these three countries, production drops precipitously.
The Organization of Petroleum Exporting Countries (OPEC) produces approximately 30 million BOPD. Although OPEC may attempt to collude and control oil prices, world history has repeatedly proved that global cartels generally cannot control markets for any sustained period of time.
This article is not about geopolitical forces, but one can quickly see that OPEC members have distinct cultures, governments, customers, and priorities, as well as different production and reserve replacement costs. Hence, it is unlikely, and perhaps even unrealistic, for OPEC members to uniformly agree on production quotas and then expect each member country to behave accordingly. Therefore, it is probably a good assumption that global oil prices will submit to global market forces; i.e., oil prices will likely continue to depend on the supply and demand equation of competing producers and consumers.
Improving Megaproject Economics Through the Use of Early Production
Authors: Wilson Adam 
Published: January 2017

This article, written by Special Publications Editor Adam Wilson, contains highlights of paper SPE 177729, “Improving Megaproject Economics Through the Use of Early Production,” by James A. Volker and Adam J. Bond, Zakum Development Company, prepared for the 2015 Abu Dhabi International Petroleum Exhibition and Conference, Abu Dhabi, 9–12 November. The paper has not been peer reviewed.
A key aspect of the project discussed in this paper is the use of minimal initial-production facilities to achieve significant early production from each of four preconstructed artificial islands. The initial-production facilities leverage the use of spare processing capacity on existing adjacent satellite platforms to allow for production from each of the islands during the 4-year period between completion of the first wells and completion and startup of the permanent production facilities.
Introduction
The project is approximately 80 km offshore in the Persian Gulf and consists of four artificial islands. The objective of the initial production phase is to provide early and sustained production from wells drilled on the islands as soon as they are available, thereby achieving advanced revenue generation and improved project economics while the permanent production facilities are under construction.
Initial startup was achieved from the first island in November 2014, followed by initial startup of the second island in April 2015. This is the first phase of the plan to increase production from the field by approximately 40%. The project is segmented into an initial- production phase and permanent production buildup phases. The initial-production phase will continue until completion of the first permanent production buildup phase in 2018.
The project achieved startup of initial production within 4 years of conceptual design in 2010 and a minimum of 4 years before completion of the permanent production facilities, thereby achieving the goal of capturing the benefits of the initial-production strategy.
Benefits and Challenges
The initial production strategy evolved and was optimized from conceptual design through front-end engineering and detailed design, resulting in the fit-for-purpose initial-production facilities for the first three islands. Given the short operating duration of the initial-production facilities, cost efficiency was the key driver in decision making. To ensure implementation of only the most cost-effective fit-for- purpose facilities, the early operating experience from the first island was used to simplify further the design of the initial-production facilities on the fourth island.