bluuebunny/crossref_metadata_2025_split huggingface dataset:
Technical Considerations in Converting Jack-Up Drilling Rigs to Mobile Offshore Production Units
Authors: Duhon R. D. , Kreider G. J. , Barnes J. E. 
Published: December 2007

Abstract
There is a growing need for converting jack-up drilling rigs to Mobile Offshore Production Units for early production, long-term testing and as a low cost reusable alternative to platforms for short life marginal fields. Installing process equipment on drilling rigs offers a unique set of challenges. These include new loads imposed upon the rig, storage of hydrocarbon liquids, gas venting and flaring, location of and installation of equipment, safety considerations and installation of pipeline risers. The specific technical challenge of converting jack-up rigs for Mobile Offshore Production Units (MOPU) is discussed with example solutions from two projects, one installed in Venezuela and one off the West Coast of Africa.
Workover Rig Operation on a Mature North Sea Platform - A Partnership for Success
Authors: Adams D. M. , Fletcher C. , Guyan G. , van Gils J. , Schenk C. 
Published: December 2007

Abstract
An economic appraisal and engineering analysis identified both the profitability and technical feasibility of installing a dedicated workover rig, in addition to the existing drilling rig, on a mature North Sea platform.
The paper discusses the formation of an alliance between a drilling contractor and a well services contractor to provide the expertise necessary to plan and execute workover operations. The paper expands on the following integral concepts included in the contract: Integration of planning and operations, utilizing the combined resources and experience of both the well services contractor and the drilling contractor.Flexible manning levels, thus allowing up and down manning as required for various activities associated with workover operations.Multi-skilling of the workover rig crews to minimise the required manpower with training under the guidance of the alliance.Co-operation of subcontractors with the concept of multi-skilling.The responsibilities and indemnities provisions in the subcontracts to reflect as closely as possible the responsibilities and indemnities provisions in the contract with the operator and main contractor..
The resulting operating contract exemplifies the optimization of resources available from a partnering agreement between contractors and operators, and illustrates the utility of clearly allocating the risk between the parties. Success of the concepts
integrated in the contract, particularly with respect to the value of partnering agreements between contractors and operators, may result in similar future agreements for managing the operator’s assets.
Automation in Cyclical Rate Primary Reservoir Significantly Reduces Beam Pump Failures
Authors: Findlay C. P. , Herring R. B. , Pike J. S. 
Published: December 2007

Abstract
Conoco, Inc. operates the Dagger Draw field in Eddy County, New Mexico (see Figure 1). The field produces 2500 BOPD/8500 BWPD/11000 MCFPD from 35 wells on beam pump. The typical well utilizes an API 87 high strength rod design with either a 912 or 1280 conventional pumping unit running 8–9 SPM with a 168" stroke length. The 7, 900-ft reservoir is under primary development.
A 20-month study is documented during which automated Pump-Off Controllers (POCs) were installed to reduce the high rod failure in the field. Data collected for six months prior to installation indicated that 35 wells averaged 9.8 rod failures per month. In the 14 months following POC installation, rod failures have been reduced 76% to an average of 2.4 per month. Automated surveillance of the POCs using a central computer has resulted in increased efficiency. Manpower requirements have been reduced by one employee in the field.
A previously unknown seven to eight day variable production cycle was observed field wide. This discovery helps to explain the failure of Conoco’s previous attempts to control the fluid pound or gas pound with time clocks.
Identifying Inhibitors of Hydrate Formation Rate with Viscometric Experiments
Authors: Kalbus James S. , Christiansen Richard L. , Sloan E. Dendy 
Published: December 2007

Abstract
Inhibiting the rate of hydrate formation with low concentration additives is an economically and environmentally attractive alternative to prevention of hydrates with large doses of methanol. Here, a method for screening possible rate inhibitors is described. In the method, a viscometer is used to follow the development of hydrate formation for water-THF solutions and for water-gas solutions at conditions favoring hydrate formation. The method was applied to about 30 different chemicals, plus binary combinations of many of these chemicals. The best chemical additives included BASF F-127, Mirawet ASC, Surfynol-465, sodium dodecyl sulfate(SDS), Mirataine CBS with polyvinylpyrτolidone(PVP), and SDS with PVP.
Underbalanced Completions
Authors: Walker Tim , Hopmann Mark 
Published: December 2007

Abstract
The majority of wells today are drilled and completed conventionally. That is, they are drilled with kill-weight fluids which may or may not be detrimental to the formation. Wells that are drilled underbalanced, with less-than kill-weight fluid, foam or air, are often exposed to damaging fluids during completion operations. Technology new to the industry or currently being developed will help eliminate these problems and allow for a true underbalanced operation. This technology includes two-stage drilling, downhole lubricators, downhole swab valves, and isolation equipment used in fracturing operations. This paper addresses these issues and the importance that they play in a successful underbalanced completion.
Educating for Leadership, Management and Teamwork
Authors: Graves R. M. , Turley J. A. , Macon B. A. 
Published: December 2007

Abstract
Beyond the mandatory aspects of technical competence, one of the most practical skills that Petroleum Engineering educators can teach students is how to work well with others. Because teamwork assignments in the classroom foster not only good communication skills but also advanced thinking skills, these assignments can provide students with the appropriate foundation for working in a corporate setting. Success in the workplace depends largely upon how well an employee gets along with others. In the oil and gas industry, the technically competent petroleum engineer who can coordinate and manage the efforts of other engineers performing traditional functions in the organization has the potential to rise to the top of the corporate ladder. Helping petroleum engineering students to become good managers and good communicators can be accomplished by teaching teamwork skills.
However, students must see the relevance of teamwork and communication assignments to their profession; otherwise, they become resentful and fail to perform will. Experience has shown us that students learn more effectively when classroom activities are directly related to their interests and have significance for the students' future work. The synthesis of academic and industry perspectives can assure that classroom teamwork experiences are relevant and timely from the point of view of the faculty, students, and industry employers. This paper presents such a synthesis and provides additional information to help define the role of the petroleum engineer in today’s multi-discipline, cross-functional corporate environment. The paper also presents the most recent feedback from both industry representatives and academicians regarding the feasibility of including teamwork and leadership instruction in the undergraduate petroleum engineering curriculum.
This feedback from industry and academia illustrates the need for continued cooperation and better communication between these two groups. Though the goals of both are similar (e.g., enhancing success and fostering excellence in the field), the means to reach those goals are often very different, and any number of representatives of the two groups would bring widely different perspectives into the discussion. To aid in understanding these similarities and differences in perspectives, this paper focuses on examining the issue from both sides.
1995 U.S. Petroleum Engineering Workforce Supply and Demand
Authors: Reece Cynthia A. , Meyer Joann M. , Takla L. A. 
Published: December 2007

Abstract
Results of the 1995 SPE Petroleum Engineering Workforce supply and demand surveys are outlined. Total engineering employment in the upstream sector is expected to decline slightly through 1997, while petroleum engineering employment will grow slightly in 1996 and 1997. The number of engineers hired, including petroleum, will decrease in 1995 but rebound in 1996 to 1994 levels. The number of petroleum engineering graduates seeking U.S. employment is forecast to decline slightly over the next two academic years. These graduates, however, should find improved employment outlooks in 1996 and 1997.
Use of a Database to Integrate Petroleum Resource and Reserve Estimates from Exploration to Production
Authors: Pollen S. , Andersen T. , Manner M. , Rustad L. J. 
Published: December 2007

Abstract
As a major Norwegian oil company Norsk Hydro is involved as operator or partner in a large number of commercial petroleum fields and exploration licenses.
The requirements for reporting reserve estimates have led to the development of a corporate database. This has improved the quality of the estimates and increased the flexibility in using approved data for different purposes.
Field Evaluation of Disc-Stack Centrifuges for Separating Oil/Water Emulsions on Offshore Platforms
Authors: Khatib Z. I. , Faucher M. S. , Sellman E. L. 
Published: December 2007

Abstract
Separate handling of fluids following a remediation/workover job or treating of slop oil emulsions has become a good practice to reduce upsets in oil and water treating facilities and to avoid production shut-in. This paper demonstrates that the use of high-speed disc-stack centrifuges can be a cost-effective process for handling these fluids, treating difficult emulsions, and generating little or no waste. The physical operation of these centrifuges as dehydrators (purifiers) and/or as deoilers (clarifiers) and their performance in various field applications are presented.
Tubing Flowrate Controller: Maximize Gas Well Production From Start to Finish
Authors: Elmer William G. 
Published: December 2007

Abstract
Many gas wells have liquid loading problems caused by oversized tubing, resulting in premature abandonment. This paper suggests that small tubing can be used in most any packeriess sweet gas well, regardless of anticipated flowrate, without restricting production capacity. A method of flowrate control is recommended that insures that tubing flow stays at rates necessary to maintain mist flow, allowing all liquids to be produced up the tubing string. Excess volumes are produced up the casing/tubing annulus, where pressure drop due to friction is usually negligible. Maintaining mist flow up the tubing is accomplished by regulating the amount of gas allowed to exit through the annulus. This single loop process is controlled using cost effective, simple, reliable, oilfield equipment.
Environmental Effects Of Discharge And Reinjection Of Produced Water.
Authors: Furuholt Edgar 
Published: December 2007

Abstract
There has been much focus on possible acute toxicity of produced water and which natural components and chemicals contributes most to the toxicity. This paper describes a method for risk analyses of discharges to sea based on exposure dose instead of the more common method using concentration. Results are presented from such analyses for the produced water from 4 Norwegian oil/gas fields. A comparison of environmental effects of discharge and reinjection of produced water is also presented based on available methods for assessment of environmental impacts.
Beneficial Reuse of Oilfield Waste Outside of the Oil and Gas Industry
Authors: Marinello S. A. , Herbert B. F. , Lillo H. , Curtice S. , Stark C. L , Redweick R. , Mohrbacher J. D. , Rubin M. 
Published: December 2007

AbstractIf a beneficial reuse of an oilfield waste can be found, that specific byproduct is no longer a waste, but a product. With such downstream use, the environmental liabilities of the former waste are, except for any packaging or transportation requirements, potentially eliminatedThere is a problem, however, with the lack of an active infrastructure to implement the process. Some states have limited programs, but participation is a problem. It is apparent that a "Waste Clearinghouse" addressing oilfield waste in conjunction with major industrial waste and feed strems in needed, but implementation remains in the future. An active network of participating suppliers and users would be the goal of such action. In order to establish the network, it might be necessary to lobby for modified legislation to provide economic motivation, perhaps through modified taxation, and to affect liability issues. The benefits for industry would be a reduction in waste disposal and associated liabilities and "virgin" feedstock requirements.From the operators viewpoint, this scenario would require a compilation of the different waste/byproduct streams and their characteristics and a prioritizing of those wastes by characteristics that might affect their reuse potential. These might include: (1) the greatest likelihood of finding a market; (2) the highest potential waste volume reduction; (3) the highest cost of disposal and (4) the greatest associated hazards.1For the industry as a whole, an inventorying of these byproducts and characteristics would be tied to the identification of consumers/outlets for specific byproducts. This might be accomplished through the funding of consultants/contractors specializing in clearinghouse activities and/or research into potential applications and uses.The industry needs to change it's view of waste/byproduct streams in order to be more aware of potential downstream uses. Existing examples of reuse can be used as models for further efforts.
Environmental Management Strategies For An Enhanced Oil Recovery Project, Trinidad
Authors: Dyal Shyam , Nijhawan Arun , Ramnath Kelvin 
Published: December 2007

Abstract
The Government of the Republic of Trinidad and Tobago has embarked on a major energy sector project to recover proven reserves of crude oil contained in onshore and offshore producing fields, using secondary recovery techniques. Onshore reserves of crude oil are produced using steam flooding techniques while offshore reserves are recovered through water injection techniques. These projects are being undertaken by Petrotrin and Trinmar Limited respectively.
An Environmental Impact Assessment (E1A) conducted prior to the start of the projects served to identify key environmental sensitivities associated with each project. Environmental Management Strategies were developed by both Companies to mitigate against the potential impacts of each project and are in various stages of implementation. These include: The establishment of Environmental Units, the conduct of employees training programmes, the implementation of preventative maintenance programmes, the introduction of new oily wastewater treatment facilities, application of environmentally acceptable solid waste disposal methods, regular monitoring of effluent quality, ensuring compliance with interim Company Standards and the development of oil spill contingency plans.
In addition, Petrotrin has begun a groundwater quality monitoring programme, a rationalization programme for storage facilities and adopted and implemented various components of ARPEL's environmental guidelines. Additional strategies implemented by TRINMAR Limited include risk analysis for submarine pipelines, a gas emission control programme and the conduct of annual Environmental Audits.
Environmental Management Act, 1995 which provides for the establishment and operation of an Environmental Management Authority, has just been enacted. However the enforcement of environmental legislation has been hampered by the lack of coherent effluent standards and regulatory agencies. The onus for managing the environmental impacts of the projects undertaken therefore lie within the respective Companies. The extent to which this is done is largely due to their management's commitment to achieving acceptable levels of environmental performance. The Environmental Management Strategies adopted by both Companies ensure that activities associated with the projects comply with their respective corporate missions and environmental policy statements.
Management of Change Reviews Improve Facility Safety and Optimize Operations
Authors: Ritchie Carolyn J. 
Published: December 2007

Abstract
Most offshore facilities are subject to periodic modifications and changes to improve operations. These improvements can take many forms, such as increased efficiency, safety and environmental enhancements, or equipment upgrades due to technical innovations. Proposed changes to an offshore facility should be reviewed prior to implementation so that facility safety and environmental protection are not compromised. Often, in the course of the management of change review, ways to optimize operations are discovered. Three case studies are discussed in this paper. These include modifications to existing equipment, structural support, safety, control and relief systems.
Encapsulated Scale Inhibitor for Use in Fracturing Treatments
Authors: Powell Ronald J. , Fischer Arlan R. , Gdanski Rick D. , McCabe Michael A. , Pelley Samuel D. 
Published: December 2007

Abstract
This paper describes the development and testing of a solid, encapsulated scale inhibitor for use in fracturing treatments. Data from laboratory and field tests are reported. Laboratory testing with a continuous flow apparatus has yielded inhibitor release rates under dynamic conditions. The inhibitor was tested to determine the minimum inhibitor concentration required to inhibit the formation of CaCO3, CaSO4, and BaSO4 scales in brine. Laboratory data were used to determine the parameters of a mathematical model to predict the long-term release rate of the inhibitor. Data from a treated well are compared with predictions of the model.
Release-rate testing in a continuous-flow apparatus shows that an encapsulated solid derivative of a phosphonate inhibitor has a sustained release profile. Temperature (100° to 225°F) and brine strength have a small effect on the release-rate profile. Coating the solid derivative makes it compatible with metal-crosslinked fracturing fluids. The coating has a short-term effect on the release-rate profile. The composition of the solid derivative has the greatest effect on its long-term release-rate profile.
A comparison between the mathematical model proposed to describe the long-term release rate of the inhibitor and actual data collected from a treated well shows a large discrepancy, likely because most of the inhibitor is not in contact with the water being produced from this well.
Development and Application of a New Upscaling Technique
Authors: Lee Jaedong , Kasap Ekrem , Kelkar Mohan G. 
Published: December 2007

Abstract
Detailed reservoir descriptions have become available with the advent of geostatistical conditional simulation and geological-engineering reservoir characterization techniques which can honor and integrate information such as core, well log, well test, geological and geophysical data. Prohibitive computational costs of flow simulations with such detail limit us to coarse grid systems. Of all the reservoir properties, permeability has the foremost effect on fluid flow. Therefore a procedure to properly scale-up small scale permeabilities to a permeability of a large scale coarse grid is needed.
This paper presents an extension of the new 3-D absolute permeability analytical upscaling method by incorporating 3D directional search and coordinate rotation procedures. The method for single-phase upscaling is applied to realistic 3-D reservoir heterogeneities and Glenn Pool Self Unit flow simulations and excellent agreement is obtained between fine and upscaled coarse grid simulations.
The paper also presents the extension of the method to relative permeability upscaling. Based on phase permeabilities, a theory of analytical upscaling for waterflooding has been developed. The method assumes steady-state flow under capillary-viscous equilibrium and calculates effective relative permeability tensors based on phase permeabilities as a function of water saturation. The preliminary results of the new two-phase analytical upscaling method in 2-D are compared with numerical results and a promising match is obtained. The new method may present a viable alternative to numerical upscaling.
A Critical Evaluation of a Steamflood Pilot in a Deep Heavy Carbonate Reservoir in Ikiztepe Field, Turkey
Authors: Nakamura S. , Sarma H. K. , Umucu T. , Issever K. , Kanemitsu M. 
Published: December 2007

Abstract
This paper presents an evaluation of a 4,430-ft deep steamflood pilot being carried out jointly by the Japan National Oil Corporation (JNOC) and Turkish Petroleum Corporation (TPAO) in collaboration with the Japan EOR Research Association (JEORA) in the Sinan heavy oil reservoir of the Ikiztepe field, Turkey. The paper discusses pilot operations and performance highlighting the problems and the corresponding remedial measures/solutions adopted. Also presented is a discussion of results of an integrated simulation history match study. The pilot is in its final phase, and has so far yielded oil-steam ratios (OSR) of 3.42 and 0.32 during the initial cyclic steam stimulation phase and the steamflood, respectively.
Hot Dry Rock: A Versatile Alternative Energy Technology
Authors: Duchane D. V. 
Published: December 2007

Abstract
Hot dry rock (HDR) is the most abundant geothermal resource, and is found almost everywhere at depth. The technology to extract energy from HDR for practical use has been under development at the Los Alamos National Laboratory for more than twenty years. During the 1970’s, the possibility of mining the heat from HDR by circulating water through an engineered geothermal reservoir was first demonstrated on a small scale. Between 1980 and 1986, a larger, deeper, and hotter HDR reservoir was constructed. This large reservoir was subsequently mated to a permanent surface plant. A number of flow tests of this large HDR reservoir were conducted between 1991 and 1995. The results of these tests have indicated that it should be practical to operate an HDR heat mining facility to produce power on a sustained basis.
An industry-led, government cost-shared project to produce and market energy generated from HDR is currently being put in place. That project should help demonstrate that HDR reservoirs can be operated to provide energy for long periods of time at rates sufficient to be commercially viable. In the longer run, additional applications of HDR technology such as water and waste treatment, and steam generation for oil field flooding may come into widespread use.