bluuebunny/crossref_metadata_2025_split huggingface dataset:
In-Situ Upgrading of Heavy Oils by Low-Temperature Oxidation in the Presence of Caustic Additives
Authors: Wiehert G. C. , Okazawa N. E. , Moore R. G. , Belgrave J. D. M. 
Published: December 2007

Abstract
The literature of the past thirty years shows that the low-temperature oxidation (LTO) of hydrocarbon liquids generally results in a more viscous end product. The In Situ Combustion Research Group at The University of Calgary has found, however, that upgrading can occur during LTO in the presence of caustic additives. Because it was believed that caustic inhibits oxidation reactions as evidenced by a reduction in or absence of coke formation, and allows the oil to upgrade by thermal cracking via a free radical mechanism, a systematic study was undertaken to investigate the effect of caustic on the LTO of heavy oil.
To date, nearly 200 LTO tests have been performed on Athabasca bitumen. These experiments were carried out by varying caustic concentrations, temperatures, oxygen partial pressures, total cell pressures, and run times. All effleunt gases were analyzed using gas chromatography, the pH of free water was measured, and hydrocarbon products underwent determination of coke and asphaltene contents, viscosity, and density. CHN and S analyses were carried out on the whole oil, and coke and asphaltene fractions.
Several instances of upgrading were observed. Optimum conditions occurred at lower caustic concentrations, lower temperatures, lower oxygen partial pressures, and longer run times. The amount of oxygen reacted appears to be the most critical parameter affecting the system. The presence of caustic apparently did not inhibit the oxidation reactions from taking place, but, rather, modified the process by impeding the asphaltene fraction from converting to coke.
Pressure-Volume-Temperature Correlations for Heavy and Extra Heavy Oils
Authors: De Ghetto Giambattista , Paone Francesco , Villa Marco 
Published: December 2007

Abstract
The paper evaluates the reliability of the most common empirical correlations used for determining reservoir fluid properties whenever laboratory PVT data are not available: bubblepoint pressure, solution GOR, bubblepoint OFVF, isothermal compressibility, dead-oil viscosity, gas-saturated oil viscosity and undersaturated oil viscosity,
The reliability has been evaluated against a set of about 65 heavy and extra-heavy oil samples. About 1200 measured data points have been collected and investigated. All measured data points are reported in the paper. For all the correlations, the following statistical parameters have been calculated: a) relative deviation between estimated and experimental values, b) average absolute percent error, c) standard deviation.
Oil samples have been divided in two different API gravity classes: extra-heavy oils for °API&lt; 10, heavy oils for 10&lt;°API&lt; 22.3.
The best correlations for each class of API gravity have been evaluated for each oil-property.
The functional forms of the correlations that gave the best results for each oil property have been used for finding a better correlation with errors reduced, on average, by 10%. In particular, for extra-heavy oils, since no correlations are available in literature (except for viscosity), a special investigation has been performed and new equations are proposed.
A Mathematic Model of Electrical Heating in Hollow Pump Rod and Its Application
Authors: Cheng Y. M. , Guo C. Z. , Gong L. 
Published: December 2007

Abstract
For heavy oil production well, especially at the situation of cold production, it is essential to maintain enough flow energy of the fluid along the wellbore, hence, the temperature distribution in the wellbore at various conditions should be made certain so as to determine the reasonable production.way and equipments. At present, the most effective measure is to heat the oil using hollow pump rod with an electric cable inside.
In this paper, a mathematic model, which was successfully estabished to represent electrical heating with a cable in hollow pump rod, is described. It considers the heat transfer mechanisms of conduction, convection and radiation and the changes of physical properties and thermal properties of mixtures of oil and water. This model is practical and the calculation results can provide basis to design the production of heavy oil well, such as power supply capacity, depth of cable, production rate etc, can be determined and optimized. Its application in Jidong oilfield, which has indicated it is very effective, is also discussed.
Development and Operation of a New Insulated Concentric Coiled Tubing String For Continuous Steam Injection In Heavy Oil Production
Authors: Luft H. B. , PeiensKy P. J. , George G. E. 
Published: December 2007

Abstract
The design, testing, construction and installation of a prototype insulated concentric coiled tubing (ICCT), 1700m in length for continuous steam injection in a horizontal well, was recently completed. The concentric tubing consists of a 1-3/4" inner and 2-7/8" outer coiled tubing separated by loose-fill insulation and specially designed composite-construction centralizers. The ICCT R & D required the development of a new, low thermal conductivity centraliser, the design of thermal expansion joints utilizing advanced seal technology suitable for a high pressure and greater than normal steam temperature of 350C (662F) and the application of modem orbital welding processes for ICCT welded connections. The experimental steam injection process consists of continuous steam injection and oil production from the same well bore. Oil production commenced
January 9, 1995 and successful operation has been achieved to date.
This paper describes and presents the results of insulation heat loss and frictional resistance laboratory testing, shop trial assembly and structural integrity testing, construction of the prototype ICCT string in a suspended vertical well and installation of the ICCT prototype in ELAN's heavy oil lease at Cactus Lake, Saskatchewan. Also presented are the results of computer thermal simulations and ICCT field performance evaluation. In addition, a comparison of the advantages of the new ICCT technology with conventional jointed thermal tubing, is presented.
Soehlingen Z10: Drilling Aspects of a Deep Horizontal Well for Tight Gas
Authors: Pust G. , Schamp J. 
Published: December 2007

Abstract
Mobil Germany's pilot-project Soehlingen Z10 had the objective to make the large gas potential of the Main Sandstone of the gasfield Soehlingen (more than 40 Billion m3 of gas-in-place) producable at economic production rates. Due to the presence of Illite, the Main Sandstone has a reduced permeability of only 10 to 20 jxD. Offset wells had proven that economic production rates are achievable by means of hydraulic fracturing.
The drilling phase was completed in July 1994 following an extensive completion and stimulation phase with four hydraulic fracs in the horizontal section of the well. A 5750 m well with a 630 m horizontal section at a TVD of 4780 m under 92 degrees inclination was drilled. Drilling the well broke several records, being the deepest horizontal well drilled and logged with the deepest liner run to TD, cemented, completed and stimulated. In the horizontal section, the deepest plug back and sidetracking operation was carried out successfully.
To ensure the operational success, several long-term plan-ning and designing steps concerning the location of the wellsite, optimization of the wellpath, required minimum mud weight for the pay zone, secure drilling of the depleted Wustrow sandstone in the Rotliegendes above the payzone and proper running and cementing of the 7" liner in the horizontal section of the well took place in MEEG's drilling group to reach the high set goals of the project. Also a number of adjustments in the plan were implemented based on the actual conditions encountered in the well.
After finishing drilling operations the completion and stimulation works were performed successfully until the first production tests began at the end of January. Production from all four fracs yielded a rate of more than 20,000 m3 (Vn)/h, in comparison to the expected rate of 15,000 m3. These production statistics indicate the overall success of this highly difficult pilot project, which hopefully may lead to success of similar projects in the future on a worldwide basis.
The Paradox of a New Oil Province - Foinaven and Clair
Authors: Smith P. J. , Daly M. , Stump M. 
Published: December 2007

Abstract
Oil was discovered West of Shetland's as long ago as 1977 with the Clair discovery. However the first oil to be placed upon long-term production will not be until 1996 with the BP/Shell development of Foinaven. Developed during those 20 years is a wealth of experience gained by the offshore industry in discovering, appraising and developing oil fields in the UKCS providing the foundation for opening up the new West of Shetland Province.
The continued commitment to explore West of Shetlands, despite a sequence of non-commercial discoveries and dry holes led to the 1992 recognition of Foinaven and subsequently its fast track to development.
The paradox of twenty years from oil discovered to oil produced in a province, against 4 years for Foinaven discovery to market is the central inquiry of this paper.
Fundamental to understanding this paradox are:
the environmental constraints,
the development of new technology,
the awareness of the business prerogatives,
and the new behaviours of all stakeholders.
We take the case history of the Foinaven field development and discuss the requirements to bring this project forward.
Direct hydrocarbon detection seismic technology, novel well techniques and extended well testing provide the basis for volumes and productivity predictions. The employment of facility solutions in harsh metocean conditions and deep waters provide no less of a technological challenge. Understanding fully the business process and the importance of pace in development against the uncertainties that such a pace invokes is paramount. The quality and maturity of the UK offshore industry is an often forgotten component, along with the strides that oil companies and regulatory bodies have made in clearing hurdles for compliance in moving together at pace.
We are left with the challenge of developing, appraising and exploring simultaneously in a new province not knowing the full extent of volume, technology or behavioural change that it will require.
The Challenges of Liverpool Bay: A New Perspective for a New Era
Authors: Pearson R. G. 
Published: December 2007

Abstract
Unique technical, environmental, safety and managerial challenges characterise the Liverpool Bay development. Yet, at the same time, operator BHP Petroleum recognises the need to transform costs associated with the project. This paper focuses on the initiatives which meet the challenges and ensure the development will be completed on time and within budget.
Re-Engineering the Alliances and Partnerships
Authors: Straughen M. 
Published: December 2007

Abstract
Introduction
For some time the Offshore Industry has recognised the need to change the way it conducts its business if it is to retain a viable economic position in the future.
I presented a paper almost three years ago in Aberdeen that considered the issue of Improving the Competitiveness of the UKCS Offshore Industry. I believe this conference is an ideal opportunity to review what has been achieved since then and what further action is needed if any, with specific regard to the issue of Alliance and Partnership Relationships.
Industry Challenges
I summarised the huge challenges that the offshore industry faced then as follows:
New Development Undeveloped fields on the UKCS are more marginal in economic terms and will not be viable if their development is tied to traditional means because since the early 1980s, offshore costs have doubled while the oil price has about halved.
Producing Fields The revenue generated by the majority of these is in decline. In addition the effort to maintain existing platforms is increasing as the installations age, and added expenditure is necessary to accommodate the changes demanded by the new safety regime in the UK.
Competition The industry is operating on a global basis, and other areas of the world hold economic attractions for the operators, particularly for new developments. While the UK's political stability and advanced offshore infrastructure are attractive features, lower pricing can be found elsewhere.
Workforce Involvement in the UK Offshore Oil & Gas Industry
Authors: Royle D. J. C. 
Published: December 2007

Abstract
Workforce involvement has received much attention in the UK offshore industry since the Cullen Report in 1990. The concept is, of course, well known. Its application to offshore safety by operators and contractors has provided the opportunity to make full use of the experience and knowledge of the whole offshore population in a controlled effort to improve safety performance. Cultural and economic pressures are reinforcing the need to maximise the full potential available from the workforce while allowing management to exercise their legitimate control. Real benefits have been achieved including improved understanding and contribution to QRA work and in the handling of emergency situations wherfe other groups effectively become an addition to the existing workforce. As safety performance improves it becomes progressively harder to achieve further gains. A genuine and enduring participation by the workforce and line management in all issues affecting safety is needed if the current progress is to be sustained.
HIPS Design and Applications
Authors: Moroney Michael C. 
Published: December 2007

Abstract
A High Integrity Protection System (HIPS) is a safety mechanismfor a process plant offering the same or better protection than a relief valve or rupture disc. Thecurrent standard for plant protection in the United Kingdom is EEMUA Publication 160', whichgives four basic categories for control and protection systems:
Category 0 System. A self acting mechanical device or system which is a protectionagainst dangers to personnel. Examples include relief valves, bursting discs or containment.
Category 1 System. A non self-acting system whichrequires an outside source of energy and which is a protection against the dangers to personnel.
Category 2 System. A system which protects against the damage to the environment, damage to the process plant, loss of product or production.
Category 3 System. A control system which ensuresreliable production and maintainsplant operation within the operational limits.
Recent North Sea Experiences Involving Fatigue Failures of Duplex Stainless Steel Piping Systems
Authors: Jungbauer David E. , Smalley Anthony J. , Linzi Paolo 
Published: December 2007

Abstract
During the past 15 to 20 years, duplex stainless steels have gained wide acceptance in the oil, gas, chemical, and refining industries. Because of their desirable mechanical properties of corrosion resistance, high strength, and light weight, the offshore oil and gas industry has been quick to recognize their usefulness. Engineering design firms have been using duplex stainless steels to greater advantage to further reduce topside weight.
When using duplex stainless piping systems, thin-wall sections can pose serious dynamic problems. Even though their fatigue properties appear to be superior to most carbon steels, many fatigue failures involving duplex steels have occurred in North Sea operations. In systems experiencing little or no mechanical dynamic excitation, fatigue failures will not be a problem. Conversely, thin-walled systems exposed to flow- induced excitation due to low frequency random turbulence or high frequency sonic, or near sonic, flow conditions involving pressure control, recycle, or safety relief valves, can be highly susceptible to fatigue failures. These failures can occur at vibration amplitudes previously considered safe in thicker wall piping systems.
Failures of this kind were experienced during the start-up of the Tiffany Platform in small diameter branch connections attached to thin-wall duplex steel gas compression piping and, although affecting only a very limited number of connections, they were symptomatic of the problems recently experienced by a number of North Sea operators.
This paper describes the problems experienced and the approach used by AGIP (UK) Limited, together with Southwest Research Institute to investigate the causes of the failures and to identify simple remedies to allow quick restoration of safe production operations. The methodology used in obtaining data such as modal impact, vibration, noise, pressure pulsation, and dynamic strain are presented. Analysis to define the nature of the problems is also discussed. The solution of the fatigue failures is set forth along with suggestions for additional research that should be performed to develop guidelines and procedures for existing and new installations.
High Efficiency Inertial Phase Separation for Offshore Platforms
Authors: Brewer Richard J. N. , Pink David J. , Atkins David 
Published: December 2007

Abstract
The separation of immiscible liquids and the removal of liquids from gases by equipment utilising inertial and gravitational mechanisms has been an integral part of offshore production operations since the first platforms were constructed. There have been few significant changes in the basic technology over the years until the recent introduction of high efficiency membrane coalescers.
This paper presents the latest experience and technology for high efficiency membrane phase separation which has only recently become available.
The paper presents a review of the theory of phase separation and equilibria along with a discussion of the key factors controlling equipment size. Different technologies will be compared and a methodology for equipment selection presented.
Finally, specific details will be given of three offshore applications detailing how this proven technology has solved real problems on gas separation and ensured that fuel specification is achieved to a gas turbine by an innovative use of a high efficiency liquid / liquid separation unit.
Workover Applications to Eliminate Sand Production in V-Fields Horizontal Wells
Authors: Paul D. R. , Burton R. C. , Davis E. R. 
Published: December 2007

Abstract
This paper describes the workover and recompletion methods used to eliminate sand production on two horizontal wells identified as sand producers. The paper discusses the selection and performance of non-damaging drill-in-fluids utilised during the workover operations. The specific procedures to install prepacked screens and clean up the wells while minimising productivity impairment are presented. Results show the workovers eliminated sand production without significantly reducing well productivity, proving this is a viable method for future well interventions.
A Novel Scale Inhibitor Chemistry for Downhole Squeeze Application in High Water Producing North Sea Wells
Authors: Hen J. , Brunger A. , Peterson B. K. , Yuan M. D. , Renwick J. P. 
Published: December 2007

ABSTRACT
This paper presents a novel scale inhibitor chemistry for achieving cost effective and extended squeeze lifetime in high water producers that can significantly reduce the number of treatments. The new and proprietary concept called Mobil Scale Inhibitor Process (MSI) is based on additives in the scale inhibitor solution that activate the phase separation of up to 85% of the total injected inhibitor during the well shut-in period following afterflush. Such an inhibitor retention is much higher than obtainable by conventional adsorption or precipitation mechanisms. The activation is temperature, time and pH driven and allows the inhibitor slug to be safely displaced into the formation before phase separation occurs. Furthermore, this squeeze chemistry am be applied to most of the commonly used scale inhibitors such as phosphino-polyacrylic acids (PPAA), polyacrylic acids and phosphonates to improve their squeeze performance. MSI is environmentally friendly and has an OCNS (Offshore Chemical Notification Scheme ) category of zero.
In corefloods with either PPAA or phosphonates under simulated North Sea reservoir conditions, this new chemistry resulted in a 2-12 fold increase in the squeeze lifetimes. Computer modeling predicts significant increase in inhibitor lifetime when applied in the field. To date, field trials by Mobil North Sea Limited support the laboratory work and well productivity was not damaged.
This new technology is believed to be a significant advance in achieving long-lasting and cost-saving downhole squeeze treatments for preventing scale deposition, particularly for for high water producing wells. Furthermore, it does not increase complexity in field operation when compared with conventional treatments.
Cost Effective Strategy for Modification Projects
Authors: Lunde Helge , Sirevaag Alf Morten , Tjåland Kjell 
Published: December 2007

Abstract
For an oil company involved in offshore oil production, the ability too effectively execute modification projects offshore is mandatory for to be able to extract the maximum economic potential of the offshore operation. Experience has shown this to be very difficult and large cost and schedule over runs has been the rule rather than the exception.
Statoil has developed a total strategy for this kind of project. The key element here is to make a short term alliance work for this kind of project while employing effective work processes and tools. The contract utilises the best from traditional bidding and alliance contracts and employs an alliance principle by utilising a compensation and risk sharing scheme that promotes common project goals for the participants. The work processes are optimised for efficiency and quality by employing fully responsible and integrated project teams, tailored project tools and procedures and an experience data bank for this kind of project. To teach the skills and motivate the involved project personnel, a purpose built training course has been developed.
Experience so far has shown a reduction of total project cost of 20 - 50%. The overall strategy is still in an early stage of its development and the potential for further improvement and development is indeed present.