bluuebunny/crossref_metadata_2025_split huggingface dataset:
The Gullfaks Field Development: Challenges and Perspectives
Authors: Tollefsen Svein , Graue Eirik , Svinddal Stein 
Published: December 2007

ABSTRACT
The Gullfaks Field is located in the Norwegian Sector of the North Sea, block 34/10, and currently has the capability of producing more than 70,000 Sm3/d of oil (440,000 stb/d) from three CBS platforms. The reservoir sands comprise shallow marine to fluvial sediments of the Cook Formation, Statfjord Formation and Brent Group, ranging in age from Early to Middle Jurassic. Water injection is the major drive mechanism for maintaining reservoir pressure above bubble point.
Development wells have confirmed a complicated structural picture with numerous faults beyond seismic resolution, causing major impacts on predicting field reserves and flow patterns. Reverse faulting in an area of predominantly normal faulting further emphasises the structural complexity.
Complex geology along with field performance after water breakthrough resulted in several changes in the initial development strategy. Production from the highly productive Tarbert and Statfjord sands was accelerated in order to compensate for the loss of production from the Lower Brent sands caused by sand production after water breakthrough. Development of complex Ness and low productivity Cook sands have recently commenced.
Gravel packing, implemented in the Upper Brent field development, provided sand control and increased production rates. Various types of chemical sand control are currently being evaluated and tested in the field. Lowering pressure in gravel packed wellbore region below bubble point may increase the production rates even further.
Following advances in drilling technology, highly deviated/horizontal wells improve recovery and accelerate field development by combining production from several reservoirs in one single well. A test programme for surfactant and WAG flooding has been implemented on the field. Other EOR methods, such as gel and polymer flooding, are currently being investigated for potential use.
Gas/Oil Gravity Drainage: Laboratory Study of Oil Reimbibition and Streaming Between Stacked Matrix Blocks
Authors: Vidal Jerôme 
Published: December 2007

Abstract
In naturally fractured reservoirs, the gas-oil gravity drainage of stacked blocks may result in an oil flow through the matrix blocks or within the fractures network. This laboratory study outlines factors affecting the distribution of oil fluxes in the fractures and in the matrix blocks.
Gravity drainage and spontaneous reimbibition tests were carried out on single blocks and on stacked blocks with capillary continuity. Experiments were performed on blocks with sealed (ID case) and open (3D case) lateral interfaces. The oil can be expelled out of the matrix and then either flows in the fracture or is reimbibed in the lower blocks. Both streaming and drainage oil rates were separately measured for various flow rates on the upper block of the stack.
Causes of the flow out of the matrix and reimbibition are discussed. They are mainly due to heterogeneity of the petrophysical properties along the stack: permeability, capillary pressures for drainage and imbibition, saturation history, fractures capillarity. The spontaneous flow rate of oil through a matrix block is not only controlled by the block permeability. It also depends on boundary conditions imposed by the upper and lower blocks due to the capillary continuity through the fractures. All the oil flowing in the fractures is not systematically reimbibed in the lower matrix blocks, as previously thought. This is essential for the production forecast of fractured reservoirs.
Numerical simulations were conducted using a finely gridded single porosity model. Comparisons with experimental results have outlined the sensitivity on some basic parameters, i.e. the capillary pressure curves and their hysteresis.
Oil Prospects In Argentina A Country With A Rapidly Growing Economy
Authors: Buckwalter John F. 
Published: December 2007

Introduction
During the years 1964 and 1965, American oil companies in Argentina were in the process of negotiating settlements with the Argentine government to recover their investments preparatory to leaving that country. This turn around of events resulted from President Arturo Illia's decision to carry through his campaign President Arturo Illia's decision to carry through his campaign promises "to eliminate the foreign oil companies and return the promises "to eliminate the foreign oil companies and return the oil wealth of Argentina to the Argentine people." This act would eliminate the oil companies who came to Argentina during 1957 and 1958 at the invitation of President Frondizi who immediately preceded Illia in office. In Argentina, the government owned and preceded Illia in office. In Argentina, the government owned and operated oil company is Yacimientos Petroliferos Fiscales or YPF. It was through YPF that the government made settlements to these oil companies.

First Contract for Ryder Scott
In June of 1964, Ryder Scott Company Petroleum Engineers received information about YPF's desire to obtain technical assistance to conduct waterflooding in several of its oil fields. This information was received in the form of a request from a manufacturer's representative in Buenos Aires who wanted to supply assistance to Ryder Scott to qualify as a bidder and then enter into competitive bidding to secure a service contract from YPF.
In view of the mass exodus of oil people from Argentina, this was a difficult decision for Ryder Scott. Most bankers said "no, don't go to Argentina." Oil companies and service companies said they were disappointed with the turn of events in Argentina.
Utilization of Chemical-Enhanced Oil Recovery Technology to Remove Hazardous Oily Waste from Alluvium
Authors: Pitts M. J. , Wyatt Kon , Sale T. C , Piontek K. R. 
Published: December 2007

Abstract
Chemical enhanced oil recovery technology can be used to remove oily contaminants from soil. Laboratory studies demonstrated that a variety of alkali plus surfactant combinations can be used with polymer to reduce waterflood residual oil saturation. In these studies, the oil saturation of laboratory corefloods was reduced to 0.01 pore volume. Waterflood plus chemical flood wood-treating oil recovery from corefloods was 98 percent of the initial oil saturation.
In addition, a field demonstration program is discussed in which alkaline-surfactant-polymer solutions were used to remove wood-treating oil from alluvium. In the first stage, performed in 1988, waterflood plus chemical flood oil recovery from the alluvium was 94 percent of the original wood-treating oil in place. The second pilot was performed a year later with a slightly different chemical injection scheme. Water-flood and chemical flood oil recovery from the alluvium was 96 percent of the original wood-treating oil in place. While the results indicate a large reduction in contaminant mass, numerous site specific issues related to the feasibility of full-scale application remain.
The Effect of Pressure and Temperature on Pore Volume Compressibility
Authors: Von Gonten W.D. , Choudhary B.K. 
Published: December 2007

Abstract
Pore volume compressibility is one of the physical properties of a reservoir that must be specified in many reservoir engineering calculations. In this research, the effect of compacting pressure, temperature and porosity on compressibility was investigated.
A total of nine different cores were tested, eight were sandstone and one was limestone. Core samples were placed in copper jackets and subjected to compacting pressure up to 15,000 PSI. Runs were made pressure up to 15,000 PSI. Runs were made at room temperature and at 400 degrees F.
Very late has been published concerning the effect of temperature on the pore volume compressibility of reservoir rock. This work shows that the pore volume compressibility increases with increasing temperature for the same pressure. In most cases, about a twenty percent increase in compressibility was noted at 400 degrees F. as compared to room temperature.
The compressibility was found to be a continuous function of compacting pressure. The compressibility at 14,000 PSI compacting pressure was only about one-third of the pressure was only about one-third of the compressibility at 1,000 PSI.
From the research that has been performed, no method has been found for performed, no method has been found for accurately predicting pore volume compressibility. Therefore, when accurate compressibility data for a reservoir are needed, laboratory measurements should be made on core samples from the specific formation simulating reservoir temperature and compacting pressure.
Introduction
In the past few years, much emphasis has been placed on sophisticated reservoir engineering such as mathematical reservoir models and transient reservoir flow tests. One of the physical properties that must be specified in this type of work is the pore volume compressibility of the reservoir rock.
The Comparison of Petroleum Contractual Systems in Asia Pacific
Authors: Partowidagdo Widjadono 
Published: December 2007

Abstract
The earnings from oil and gas sales are a very important source of income for some countries in Asia Pasific Region. The hydrocarbons are also important source of energy for almost all of the countries in the region.
Most governments in this region invite foreign companies to their countries to supply the risk capital for petroleum exploration and development in exchange for a direct share in the potential profit.
In this study, a comparison of different hydrocarbon fiscal systems and profitability in Asia Pasific Region is presented.
Reusable Platform Concepts
Authors: Gudmestad O. T. , Sparby B. K. , Stead B. L. 
Published: December 2007

Abstract
There is an increasing need to reduce costs of offshore production facilities in order to make development of offshore fields profitable. For small fields with short production time there is in particular a need to investigate ways to reduce costs. The idea of platform reuse is for such fields particularly attractive. This paper will review reusable platform concepts and will discuss their range of application. Particular emphasis will be placed on technical limitations. Traditional concepts as jackups and floating production facilities will be discussed but major attention will be given to newly developed ideas for reuse of steel jackets and concrete structures. It will be shown how the operator for several fields can obtain considerable savings by applying such reusable platform concepts.
Cost-Effective Gas Control: A Case Study of Surfactant Cement
Authors: Hibbeler J. C. , DiLullo Gino , Thay Michael 
Published: December 2007

Abstract
Gas migration during primary cementing has been the subject of numerous studies and is well documented in referenced literature. Methodologies to predict gas flow potential have been devised and various systems have been offered to prevent the phenomenon. However, high cost associated with these systems has made them unattractive for many well candidates having marginal potential for gas flow. This prompts the possibly unsafe choice between merit and economics. With this in mind, a cost effective slurry was developed, incorporating surfactant to prevent annular gas flow.
Surfactant cement is a conventional slurry to which a foam generating surfactant is added. Originally developed in 1973 by the Institute Francais du Petrol, surfactant cement has been utilized in several applications worldwide. Surfactant immobilizes formation gas by converting it to a highly viscous low mobility foam. The addition of surfactant also lowers a slurry's surface tension, thereby preventing bubbles from coalescing and becoming mobile. The combination of these two mechanisms combined with thoughtful slurry design will greatly reduce the risk of annular gas flow after cementing.
The purpose of this paper is to illustrate, via case study, the cost effectiveness of surfactant cement when used for gas control purposes. A brief overview of annular gas flow causes, conventional aspects of gas control slurry design, and description of surfactant gas control mechanisms are also presented.
Towards Common Technical Standards
Authors: Rahmat Hussein , Suardi A. R. 
Published: December 2007

Abstract
In 1989, PETRONAS launched its Total Quality Management (TQM) programme. In the same year the decision was taken by the PETRONAS Management to introduce common technical standards groupwide. These standards apply to the design, construction, operation and maintenance of all PETRONAS installations in the upstream, downstream and petrochemical sectors. The introduction of common company standards is seen as part of an overall technical management system, which is an integral part of Total Quality Management.
The Engineering and Safety Unit in the PETRONAS Central Office in Kuala Lumpur has been charged with the task of putting in place a set of technical standards throughout PETRONAS and its operating units.
Several options have been evaluated. The strategy which was finally selected involved the acquisition of standards from major oil companies (rather than re-inventing the wheel and creating new standards) and converting these standards into sound PETRONAS Technical Standards (PTS).
The PTS are based on, and need to be used with, recognised international, national and industry standards.
The PTS are complementary to relevant external standards such as ISO, IEC, API, MS and reflect PETRONAS Management Policies regarding Safety, Health, Environment and Technical Integrity.
Several of the frequently used national and industry standards which are accepted worldwide in the oil and gas industry are now being proposed to become, after minor adaptation, international standards.
The PTS therefore, will increasingly be based on international standards.
The Acquisition of standards from three companies has been completed and the Implementation Programme has been under way for about one year. Several PETRONAS Operating Units (OPUs) are already using the PTS, others are in the process of gradually introducing them. Steering and Working Committees have been set up while Custodians and OPU Focal Points have been identified. Input and feedback from the OPUs in the field is vital to achieve Standards which are fully acceptable.
Special tools such as the CD-Rom system. Standards Manuals and Document Control Systems have been developed and are being implemented.
PETRONAS has set 1997 as target to complete the conversion and adaptation process for the PTS.
Meeting the Challenge of Extremely Corrosive Service: A Primer on Clad Oilfield Equipment
Authors: Pendley M. R. 
Published: December 2007

Abstract
Extremely corrosive environments, such asthose often encountered in deep, hot, sour oil and gas wells, are usually characterized by the presence of hydrogen sulfide (H2S), carbon dioxide (C02), Chlorides, and other corrosive species coupled with high temperatures (&gt;400°F/204°C) and high pressures (up to 20,000 psi/138 MPa). Most low alloy and stainless steel materials are not suitable for such environments.
Extremely corrosive Service conditions dictate the use of a corrosion-resistant alloy (CRA) in areas which are exposed to the hostile environment. However, it is often cost-prohibitive to make an entire component out of CRA material. An alternative strategy is to use a low alloy steel for the bulk of the component and clad critical surfaces with a corrosion-resistant material. Clad equipment can provide excellent corrosion resistance in hostile environments atafraction of the cost of 100% CRA components.
This paper will detail the problems posed by extremely corrosive environments and discuss how clad equipment provides a cost-effective solution.
The Changing Role of Reservoir Engineering in the Airlie Project
Authors: Della Lou , Anderson B. D. 
Published: December 2007

Abstract
This paper discusses the changing role of reservoir engineering in the various stages of a marginal development offshore Western Australia known as the Airlie Project. The project, which comprises three thin oil column fields, South Pepper, North Herald and Chervil, was made possible through an innovative approach to development. This included the pioneering of horizontal well technology in Australia, the use of a jackup drilling rig as a production platform and the application of monopod and minimal structure concepts for wellhead Support. Specifically the paper addresses the use of horizontal and high angle slant production wells in marginally economic thin oil columns, and discusses the successes, the failures and the general philosophy applied to the development. The results of several numerical reservoir Simulation studies are used to illustrate these aspects.
The evolution of the role of reservoir engineering is followed from the feasibility stage through the initial development, to the mature stage including two infill drilling programs in South Pepper, and finally to the future twilight phase of the project. The applicability and reliability of reservoir modelling at various points in the project life are reviewed. A critical feature of the reservoir management of thin oil column reservoirs has been the almost continuous remapping process as additional data was acquired and the necessity for detailed geological flow unit description. A multi disciplinary team approach has therefore been of great importance in achieving an integrated reservoir management plan.
Foremost in the development success of marginally economic fields such as those in the Airlie Project, has been the application of new technology including MWD logs, gas wetness ratios and modern Simulation tools. The use of reservoir Simulation has been instrumental in the optimisation of horizontal well placement within the thin oil columns which are continually rising as gas caps become depleted. It was concluded from reservoir Simulation studies and appraisal drilling that future horizontal wells drilled in these thin oil columns should be placed as high in the remaining oil column as possible.
Utilization of Horizontal Wells for Secondary Oil Recovery
Authors: Reeves S. R. , Strickland T. A. , Crawford P. B. 
Published: December 2007

Abstract
Horizontal drilling for primary oil recovery has become a routine practice in some areas of the United States, with more than 2,700 wells drilled nationwide1 averaging horizontal extensions of 1,500 to 3,500 feet. Frequently these wells are targeted for achieving a near perpendicular intercept with natural fracture Systems in reservoirs having a substantially vertically fractured matrix. Many such horizontal wells have resulted in oil production rates more than sufficient to payback the higher well expense in as short as a few weeks. This rapid payout has provided the incentive for drilling additional horizontal wells, thus advancing horizontal well drilling technology.
It would appear that horizontal wells may also find application in certain secondary or enhanced oil recovery projects. Primarily for this reason, a reservoir modeling study was performed to determine the possible use of horizontal wells to optimize the performance of such projects. From the study it was leamed that both the length and the Orientation of horizontal wells have a very significant effect on the areal sweep efficiency of commonly utilized oil displacement processes; sweep efficiencies ranged from near zero percent to almost one hundred percent of the pattem area and were found to be dependent primarily upon the well length and Orientation.
The incremental costs of drilling horizontal wells were investigated in combination with the projected increase in oil recovery over vertical wells. The economics of horizontal wells for improved recovery were then evaluated and found to be highly attractive when the horizontal legs were favorably oriented.
Improving Gravel Packing Techniques in Brunei Darussalam Field Trial Results
Authors: Welling R. W. F. 
Published: December 2007

ABSTRACT
Since the IMPAIRMENT TESTS carried out in May 1989 improvements have been made to BSP's operating practices such as better shearing and filteating of the gravel carrier fluid and the introduction of new well bore cleaning procedures. A new earner fluid viscosifier, SHELLFLO-S, was successfully tested. Likewise, pre-packing the perforations prior to running the WWS was carried out either through the TCP string or the perforation washing tool. No significant productivity increase was observed Further with pre-packing were carried out. data are, bowever, not yetavailable.
A Quality Improvement Project addressed the gravel packing process and identified some the possible uses of impairment was finalised. This result in further field trials in which the perforation was incased by either double perforating (21-24 spf) or guns (7". This was done in combination with perforation washing. A furfber move away from s/urry pac/ong fowards convenf/ona/pacWhg us/ng an/n-fne b/ender was made and a few we//s were packed us/ng/ow v/scous bnne as earner f/u/d.
Light Workover
Authors: Rachmat Elwin , Suzanne J. G. , Boibien C. G. 
Published: December 2007

ABSTRACT
The complexity of typical completions in Handil & Bekapai fields, i.e. dual completions in deviated wells to produce selectively 2 to 6 productive layers, leads to very delicate and expensive workovers.
In order to increase oil and gas gain, as well as to increase water-injection points without having to pull out the existing completion string, a light workover (LWO) System has been applied in both fields. LWO operations (which include additional perforations, isolation of perforations or communication by cementation, and gravel packing) may involve either slickline, electrical wireline, snubbing, cementing / gravel packing units or any combination of the above, but neither drilling nor work-over unit is involved. LWO's are the last chance to produce a zone having insufficient potential to justify economically a Heavy Work Over by using drilling or workover unit.
Since 1986 up to August 1992 TOTAL Indonesie has performed 103 LWO jobs which have obtained an additional cumulative production of more than 6.4 million barreis oil and 13.8 billion SCF gas and an additional 10 million barreis injected water.
The total cost for such jobs was 7.2 million USD or an average of 69 620 USD / LWO. Compared to heavy WO's (pulling out the existing completion string & running in hole a new one) which cost between 0.75 to 2 million USD each, LWO is really the cheapest solution as long as the WO goal is achieved.
Interpretation of Pulsed-Neutron Data in Low-Salinity Environments Without Base Logs
Authors: Aldred R. D. 
Published: December 2007

ABSTRACT
Conventional methods for monitoring the movement of formation fluid contacts in low salinity environments, using pulsed-neutron-capture (PNC) logs, employ the "time lapse" technique. This technique is based on the comparison between base logs recorded before production commenced and logs recorded later in the life of a producing well. The recording of a base log requires the well to be re-entered some weeks or months after completion and, in the case of fields which are developed using subsea completions, this is not practical.
This paper describes a technique which was developed to interpret PNC logs in low salinity environments without the need for base logs. The technique involves Computing synthetic base logs from the open hole log Interpretation of a well and the sigma response to each mineral and fluid in the formation. This method has proved successful in the monitoring of changes in oil-water contacts in two fields in the Timor Sea, Jabiru and Challis, both of which have formation water salinities of about 40,000 ppm, NaCl equivalent.
Verification of the accuracy of the technique is provided by means of monitoring the change in natural radioactivity in the formation due to water movement This has been observed by changes in relative gamma ray responses between open hole and cased hole logs beneath the new oil-water contacts.