bluuebunny/crossref_metadata_2025_split huggingface dataset:
New, Low-Viscosity Acid-In-Oil Emulsions Provide High Degree Of Retardation At High Temperature
Authors: Crowe C.W. , Miller B.D. 
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.
This paper was prepared for the Rocky Mountain Regional Meeting of the Society of Petroleum Engineers of AIME, to be held in Billings, Montana, May 15–17, 1974. Permission to copy is restricted to an abstract of not more than 300 words. Illustrations may not be copied. The abstract should contain conspicuous acknowledgment of where and by whom the paper is presented. Publication elsewhere after publication in the JOURNAL OF PETROLEUM TECHNOLOGY or the SOCIETY OF publication in the JOURNAL OF PETROLEUM TECHNOLOGY or the SOCIETY OF PETROLEUM ENGINEERS JOURNAL is granted upon request to the Editor of the PETROLEUM ENGINEERS JOURNAL is granted upon request to the Editor of the appropriate journal provided agreement to give proper credit is made.
Discussion of this paper is invited. Three copies of any discussion should be sent to the Society of Petroleum Engineers office. Such discussion may be presented at the above meeting and, with the paper, may be considered for publication in one of the SPE magazines.

Abstract
A highly retarded acid emulsion has proven extremely effective in the stimulation of hot limestone and dolomite formations. The level of reaction rate retardation achieved with this acid is much greater than previously possible and is obtained through use of a unique surfactant system which both emulsifies the acid and forms a chemical barrier on the surface of the rock. Acid reaction rate studies performed in the laboratory under both static and flowing conditions demonstrate its high level of retardation.
In contrast to previous emulsified acids, which depend upon high viscosity for retardation, this emulsion has a viscosity of only 30 cps, thus greatly reducing pumping pressure and allowing increased injection rate. Due to its slow reaction rate and improved pumpability, acid penetration distance is greatly increased. Comparative well results clearly demonstrate the increased effectiveness of this type retarded acid.

Introduction
Most acid treatments can generally be classified as either fracture or matrix acidizing. Matrix treatments are performed at pressures below that required to produce hydraulic fracturing and have as their main purpose the removal of formation damage in the area immediately around the wellbore. Acid fracturing treatments are performed at pressures above fracturing pressures, usually at greatly increased injection rates. pressures, usually at greatly increased injection rates. These treatments are designed primarily to improve the natural flow characteristics of the well by the creation of artificial flow channels deep into the formation. In contrast to ordinary hydraulic fracturing where fracture conductivity is produced by the placement of sand or other propping agents acid fracturing achieves conductivity by propping agents acid fracturing achieves conductivity by the non-uniform etching of the fracture faces.
Capital Formation In The Energy Industry
Authors: Marx James F. 
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.
This paper was prepared for the 1974 Eastern Regional Meeting of the Society of Petroleum Engineers of AIME, to be held in Washington, D.C., Nov. 14–15, 1974. Permission to copy is restricted to an abstract of not more than 300 words. Illustrations may not be copied. The abstract should contain conspicuous acknowledgment of where and by whom the paper is presented. Publication elsewhere after publication in the JOURNAL paper is presented. Publication elsewhere after publication in the JOURNAL OF PETROLEUM TECHNOLOGY or the SOCIETY OF PETROLEUM ENGINEERS JOURNAL is granted upon request to the Editor of the appropriate journal provided agreement to give proper credit is made.
Discussion of this paper is invited. Three copies of any discussion should be sent to the Society of Petroleum Engineers office. Such discussion may be presented at the above meeting and, with the paper, may be considered for publication in one of the SPE magazines.
A simple, but unrealistic conclusion to draw from the existing energy shortage is that never before have so many done so much to achieve so little. With the help of the media and doomsday forecasters the good news has been overshadowed by the bad. Through the ages man has invariably, with varying degrees of success, managed to apply fresh ideas and technology to achieve his needs.
Recently we experienced results of Government intervention in the realm of supply and demand - the action taken being wage and price controls. Historically, shortages are best relieved when prices are allowed to exercise their influence on consumer habits and thus create a motivation for producers. How else can a real expression of values emerge in a realistic fashion? Perhaps some of you witnessed a recent film clip on an 11 o'clock TV news broadcast depicting Wisconsin cattlemen slaughtering calves in protest against recent feed costs coupled with an inability to achieve offsetting higher cattle prices. Taken into our own perspective, in 1954 the FPC was empowered to set artificial well head prices on interstate sales of natural gas-stimulating consumer demands, but discouraging producer incentive to promulgate continued supply in sufficient quantity. Hopefully none of us here today subscribe to the theory that government intervention in the marketplace is the panacea for a faltering system caused by an inability panacea for a faltering system caused by an inability to provide an adequate supply of a commodity at a fair price. price.
Formation Fracturing with Foam
Authors: Blauer R.E. , Kohlhaas C.A. 
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.

Abstract
Over sixty wells have been treated with hydraulic fracturing techniques with foam as the fracturing fluid. These foams contained as much as 95% gaseous phase; most treatments used foams with gas contents in the 65% to 85% range. Foam has several desirable properties for use as a fracturing properties for use as a fracturing fluid: high sand-carrying and sand-suspending capability, low fluid loss, low hydrostatic head, low pressure drops due to friction, quick fluid recovery, low formation damage, and no reduction of fracture conductivity due to fluid ingredients. Most applications of foam as a fracture fluid have been in low permeability gas reservoirs. Several permeability gas reservoirs. Several oil reservoirs have also been successfully treated, however. Cost of the treatment is approximately the same or slightly less than a treatment with conventional fluids of comparable volume and rate.

Introduction
Foams used as fracturing fluids are dispersions of gas, generally nitrogen, in a liquid, generally water, with a small amount of surfactant foaming agent added. Volumetric gas content (referred to as foam quality) is generally between 65% and 85%. Qualities as high as 95% have been used. Surfactant content is commonly 0.5% to 1% of liquid volume. Stability is increased by addition of more surfactant, whether foaming agent or gelling agent. Such foams are homogeneous mixtures with a narrow range of bubble size, mean bubble size less than 200 microns, and are stable for periods of several hours.
During a fracture-treatment operation, the liquid phase passes through a blender and is mixed with sand and then passes through the injection pump which raises the pressure to required injection pressure. Surfactant foaming agent is added downstream of the injection pump and gas is introduced with a tee or lateral downstream from the surfactant. Foam is generated at the point of gas introduction (see Figure 1). The gas is transported to the site and stored in cryogenic tanks and added to the injection stream at line pressure.
The foams used for fracturing are similar to those described previously by several investigators.
Increasing Availability - The Benefits of Introducing an Integrated Corrosion Management System
Authors: Nielsen Mette Fraas , Bingham Simon 
Published: December 2007

Abstract
Oil and gas operators are continuously encouraged to reduce operating costs per Barrel of Oil Equivalent (BOE) by minimising operations costs and optimising operability. A proactive approach to corrosion management is, for one operator, proving to be successful, whilst maintaining a safe operation ensuring no accidents, harm to personnel, or damage to the environment.
Apache Energy Limited (AEL) have developed a Corrosion Management System (CMS) using factors and resources already available and supplemented them where appropriate, with additional elements:
– A Risk and Consequence based approach to Corrosion Risk Assessment (CRA) and Inspection Scheduling was used. – Initial effort identified existing elements that could remain in place and supplemental elements required to form a cohesive, focused and commonly applicable system. – The supplementary elements of the CMS were implemented on an ongoing basis, dealing with the priority parts first, building around existing elements. – Core staff and competent personnel operate the CMS with minimal input. Ownership of the system by on-site operators and others in the field is a key factor to its success. – The CMS specifies anomaly criteria and target values for all data sets collected via manual and automated instrumentation for feedback, trending and comparison.
The feedback loop is essential for the continuous improvement of the system. Audit of technical practices and adherence to the documented requirements is undertaken periodically and independently.
The AEL CMS currently covers the East Spar and Harriet Gas Gathering Projects though has been implemented such that extension to cover other facilities is relatively straightforward. A CMS can be implemented any time during the life of the plant, facility or asset. Early implementation of the system will maximise the benefits of the system. Towards the end of the life of a plant the cost benefits may be limited.
P. 241
A Multiple Realisation Approach to Managing Uncertainty In The North Rankin Gas Condensate Field, Western Australia
Authors: Twartz S.K. , Gorjy F. , Milne I.G. 
Published: December 2007

Abstract
A multiple realisation approach was used in the management of ultimate recovery uncertainty of the North Rankin gas condensate field. The aim of this approach was to identify the key uncertainties that impact ultimate recovery, reflect those uncertainties in discrete realisations as represented on a realisation tree, use the discrete realisations to improve the quality of development decisions, and to evaluate the uncertainty on field ultimate recovery. Emphasis was placed on the use of production data, primarily pressure and TDT data, to reduce the range of possible realisations, assign probabilities to realisations and hence reduce the ultimate recovery uncertainty.
This paper provides a clear and practical process for management of uncertainties from the probabilistic and deterministic perspective. The process is comprehensive and covers all steps leading to final reporting of field ultimate recovery. The steps in the process are clearly demonstrated by actual examples from the North Rankin study.
P. 261
Transversely Fractured Horizontal Wells: A Technical Appraisal of Gas Production in Australia
Authors: Crosby D.G. , Yang Z. , Rahman S.S. 
Published: December 2007

Abstract
A large, though relatively untapped tight gas resource is thought to exist within Australia. Experience from the North Sea and the United States suggests that transversely fractured horizontal wells may be used to exploit tight gas resources more effectively than more conventional means, such as fractured vertical wells or fully completed horizontal wells. However, transversely fractured horizontal wells are relatively expensive completion options, and are commonly afflicted by complications associated with complex fracture geometries. Therefore, careful planning and screening of prospective reservoirs is essential. Using an analytical pseudo steady state inflow model, this study reviews the reservoir conditions required for the successful application of transversely fractured horizontal wells. To avoid fracture reorientation, transverse fractures should ideally be initiated directly from the wellbore and possess no longitudinal components. Reservoirs which possess natural fractures or create large differential stresses across horizontal wellbore sections will be predisposed towards the successful placement of transverse fractures. Guidelines are presented which enable the identification of such reservoirs. A case study has been performed which demonstrates the applicability of transversely fractured horizontal wells in the context of Australian tight gas reservoirs.
P. 315
Competence Skills Portfolio for Technical Staff - A Career Development Focus
Authors: Adams D.R. 
Published: December 2007

Abstract
This paper outlines Woodside's Competence Development Process. It explains how competence relates directly to performance improvement and how it relates to other processes such as Position Descriptions, Recruitment, Promotions, Performance and Development reviews and Talent Spotting, etc.
During 1996 it was decided to enhance the focus on both Performance and Competence at an organisational, departmental and individual level. The reason for the increased attention was to: - Elevate performance.
– More closely align organisational, departmental and individual targets so that people spend their time doing activities which improved performance. – Equip individuals with the specific skills, knowledge and abilities they need to be able to meet their own and their group's targets. – Provide a mechanism for the selection of individuals for positions to be made on the basis of competence.
Woodside like most companies, have a number of Human Resources systems designed to improve the capability of our employees by improving their competence. However these are only INPUTS and unless they are focused on achieving the desired OUTPUTS they will not necessarily result in improved performance, even if they improve the individual employee's personal development. This can be depicted as follows:
To ensure competence was used to improve performance it was necessary to develop an improved process for identifying competence and applying it to workplace requirements.
P. 375
Outsourcing of Minor Material Purchasing
Authors: Foley Peter W. 
Published: December 2007

Abstract
Within all organisations and particularly in the oil and gas industry there is a need to procure items of minor dollar value. These items may be small specialised items or straight consumables and normally add very little to the core business of an organisation if the items are not readily available. The process of minor material procurement typically does not add value to an oil and gas operator in terms of efficiency and economics. This paper outlines the recognition that minor material procurement is typically a non value adding activity. A number of topics are presented to illustrate the approach and the benefits of outsourcing minor materials procurement. Purchasing statistics are reviewed followed by the introduction of a strategic approach to guiding procurement to a value adding activity. The methodology used in the outsourcing and the concepts that have been implemented are discussed.
P. 393
Trends For Future Gas Supply Planning For Gas Utilization Projects In Malaysia
Authors: Abdullah Mohamad 
Published: December 2007

Abstract
The Malaysian gas era started in 1983 with the commencement of the LNG project in Bintulu, Sarawak. This was followed by the Peninsular Gas Utilization Project (PG U) and the Sabah Gas Project in 1984. The gas resources in Sarawak are developed mainly for supply to the LNG project, for export to Japan, Korea and Taiwan with a small portion consumed domestically for power generation and as feedstock to fertilizer plants.
The gas resources in Peninsular Malaysia are developed mainly for domestic utilization with some 150 million SCF/D exported to Singapore. The gas from the PGU project in Peninsular Malaysia is consumed for power generation, industrial and residential usage. In addition, the gas is also used as feedstock to a more value added petrochemical industry.
Gas has now become a major contributor to the national economy besides oil. It has a dual role as a source of energy and a major exchange earner for Malaysia. To ensure that gas continues to play this important role, a long tern, sustainable gas supply is vital for Malaysia. To meet the future growth in gas demand both for export and domestic consumption, gas production in Malaysia is projected to increase from the current level of 5,300 million SCF/D to about 6,600 million SCF/D by year 2002.
The paper will discuss an evaluation of future challenges relating to gas supply planning in order to meet the projected long term gas demand in Malaysia. Trends in expected future discoveries, development concept, development technology and project economics will also be discussed.
P. 489
Predicting the Stability of Horizontal Wells and Multi-Laterals — The Role of In Situ Stress and Rock Properties
Authors: Moos D. , Peska P. , Zoback M. D. 
Published: December 2007

Abstract
Drilling problems frequently result from severe mechanical failure of the wellbore wall and thus depend on the interplay between the magnitude and orientation of in situ stresses, rock strength, mud weight, and the orientation of the wellbore. Utilizing a new suite of software tools developed to study wellbore stability in a wide variety of geologic environments, we can accurately predict optimally-stable wellbore trajectories from knowledge of the stress tensor. The analysis is a two step process – first, we determine stress from observations of failure in existing wells. We can then apply this knowledge to predict the stability of proposed wells both while drilling and later during production. We illustrate this type of approach using three case studies. First, we combine observations of failure in a vertical well with rock strength measurements to demonstrate the feasibility of horizontal drilling in poorly consolidated reservoir sands. Next, we analyze the stability during production of a series of multilaterals drilled from a single inclined parent well. Finally, we show that wellbore stability can be controlled by the orientation of a well with respect to bedding, and illustrate a method to optimize the trajectory of wells to account for this effect.
Optimum Fluid Design for Drilling and Cementing a Well Drilled with Coil Tubing Technology
Authors: Svendsen Ø. , Saasen A. , Vassøy B. , Skogen E. , Mackin F. , Normann S. H. 
Published: December 2007

Abstract
This paper describes the strategy, design and the drilling fluid and cement operations in the first two wells drilled with Coil Tubing on the Gullfaks field. The strategy and design is explained in great detail. Excellent hole cleaning was achieved in both wells.
A serious problem of differential sticking was eliminated by a radical change in drilling fluid strategy and design. It was possible to successfully drill a 3 ¾" hole, log and run/cement a 2 7/8" liner at a maximum inclination of 122°.
A virtually solids free Potassium Formate Brine/Polymer drilling fluid with a density from 1.50 – 1.56 g/cc was used. The flow properties of the drilling fluid is characterised by a very low fluid loss due to a high extensional viscosity, a low viscosity at all shear rates and a low degree of shear-thinning.
Heavy Crude Production from Shallow Formations: Long Horizontal Wells Versus Horizontal Fractures
Authors: Valkó Peter P. , Economides Michael J. 
Published: December 2007

Abstract
This paper studies the feasibility of producing heavy oil from shallow formations using either long horizontal wells or short horizontal wells fractured horizontally. The suggested withdrawal configuration provides excellent well / fracture communication and additional sand control. The problem of optimum proppant placement is solved in two steps. First, finite conductivity fracture performance is considered in general terms. It is shown that the performance can be described as a function of two dimensionless parameters. Optimum conditions are derived. Then the solution is applied to the horizontal fracture configuration. The performance is compared to that of a "long" horizontal well.
Sleeving-back of Horizontal Wells to Control Downstream Oil Saturation and Improve Oil Recovery
Authors: Greaves M. , Saghr A. M. 
Published: December 2007

Abstract
Air injection is developing as a broad based IOR technology, applicable over a wide range of reservoir conditions, including heavy, medium and light oils. In remote and offshore locations, air represents a cheap source of injection gas for implementing a number of different recovery processes. In light oil reservoirs, there are three possibilities: if the oil-rock matrix reactivity is low, then the oxidation reactions will be limited to low temperature oxidation (LTO) and either the net thermal effect in the reservoir will be close to zero, i.e. isothermal at a low gas rate, or a thermal displacement will develop at significantly higher temperatures (still LTO), but only at a much higher gas injection rate. If, on the other hand, the oil-rock reactivity is high, high temperature oxidation (HTO) reactions will take place which, with a sufficiently high air injection rate, an in-situ combustion front can be propagated through the reservoir. A necessary requirement for all air injection processes is that the oxygen be completely removed via oxidation reactions, or at least to a sufficiently low level.
One problem observed in light oil reservoirs is the tendency to de-saturate the oil layer downstream of the moving front, particularly with thermal IOR processes, because of the additional vaporisation which occurs and high oil mobility. Low pressure ISC tests were carried out in a 3-D cell equipped with an extensive thermocouple array. In order to restrict the de-saturation of the oil layer, a modified horizontal producer well, incorporating a ‘sleeve-back’ principal was used. The idea was to mimic the ‘Toe-to-Heel’ displacement process occurring during heavy oil recovery, wherein the downstream oil is essentially immobile due to its high viscosity. The ‘sleeve-back’ of the well was achieved using a co-aligned, two well assembly, so that the upstream section of the horizontal producer well is active, and continually adjusted during propagation of the combustion front.
Significant improvement in overall stability of the process was observed using the ‘sleeve-back’ modification, as attested by sustained propagation of the combustion front, high levels of produced CO2 and high oil recovery.