bluuebunny/crossref_metadata_2025_split huggingface dataset:
In the Driver's Seat with LWD Azimuthal Density Images
Authors: Ballay Gene , Al-Ali Hussein , Amos Scott , Dennis Bob 
Published: December 2007

Abstract
Formation evaluation has been historically done ‘after the fact’, by means of wireline logs run at either an intermediate casing point, or when the well had been TD'ed. While this procedure is clearly inefficient in unexplored areas, there is also significant room for improvement in even relatively developed areas, if only one were able to measure and analyze formation attributes just after drill bit penetration. Ruggedization and miniaturization of the electronics have yielded tools that can be placed just behind the drill bit: increasingly efficient data transmission protocols permit ever more data to be examined, in real time. Saudi Aramco utilizes this technology for both real-time formation evaluation, and well-bore trajectory optimization.
The basic Logged-While-Drilling (LWD) service includes gamma ray (GR), density-neutron porosities (Rhob-NPhi) and resistivities at a variety of depths of investigation, transmitted up-hole at sufficient resolution to allow real-time formation evaluation. With this information one is in a position to quantitatively monitor local reservoir quality, and to make recommendations with regard to wellbore trajectory (deflect up or down, etc) and wellbore length (drill ahead, TD early, etc). One is not, however, able to address reservoir geometry questions (bed dip), which also have a direct bearing on the ‘drill ahead question’.
Modern LWD services include azimuthal gamma ray, density and resistivity measurements, which ‘look’ up, down and to the side. As the wellbore intersects various reservoir features, well-documented sinusoidal patterns present themselves visually in the data, and when coupled with real-time directional survey measurements allow one to deduce the local reservoir geometry. Formation evaluation personnel are literally " in the driver's seat " and can steer the wellbore either through or along (depending upon the circumstances) the feature of interest. One can furthermore extrapolate this local geometry (as opposed to field averages) geometry over to the next drilling location, and therefore compound the value. These capabilities are illustrated with actual data sets, in a development well environment.
Positive Returns from an ISO 14001 Environmental Management System
Authors: Al-Lamki F. 
Published: December 2007

Abstract
In 1999, Petroleum Development Oman LLC (PDO) obtained ISO 14001 certification for all its production and service operations. PDO was the first major E&P oil company in the Middle East to achieve the ISO 14001 certification. The certification process helped PDO to develop a culture of environmental awareness at all level, which has started providing positive returns in environmental performance. In addition, the certification re-inforced PDOs already high reputation in the country as a environmentally responsible operator. After the certification, PDO was seen as a pioneer both at local and regional scale, with peer companies consulting PDO on achieving higher standards in environmental management.
Risk Based Assessment of Storage Well Rehabilitation
Authors: Terchek Sean T. , Amick Paul C. , Newman Mark A. 
Published: December 2007

Abstract
Today's competitive environment within the natural gas industry requires gas storage operators to apply various risk management practices to effectively maintain and manage gas storage facilities. One operator's business management strategy includes tracking two key monitoring and maintenance parameters - reservoir integrity and storage well mechanical integrity. Reservoir integrity management consists of applying recognized standard reservoir engineering methods to monitor pressure and volume relationships. A storage well Condition Assessment Program is proposed to provide a consistent means to monitor and assess storage well mechanical condition in order to optimize limited capital resources applied to asset integrity management.
A relative risk assessment methodology is proposed to identify candidates for storage well reconditioning programs. A standard relative risk equation is applied to generate a relative risk profile based on certain probability of failure and consequence of failure parameters. By normalizing the information used in evaluating mechanical condition, wells within a controlled population are examined as possible reconditioning candidates.
Optimizing Drill-in Fluid Composition on Filter Cake Lift-off Pressure for Openhole Completion Offshore Applications
Authors: Queiroz João 
Published: December 2007

Abstract
This paper presents experimental results of a technique for minimizing the lift-off pressure of the mud cake generated by biopolymer/CaCO3 drill-in fluid (PDIF) used in horizontal well drilling.
The first stage of the work comprised the identification of the most influential variables in the lift-off process of the mud cake. Thus, from a group of seven suitable variables, mostly related with the composition of the fluid, the use of the technique of experiments factorial allowed to identify the permeability and the concentrations of the starch and of the calcium carbonate as the most influential in the lift- off process2.
Another group of experiments, this time with the calcium carbonate, showed that the minimization wanted in the lift-off pressure of the mud cake could only be reached through the use of concentrations of calcium carbonate of 50.0 lb/bbl.
Besides, other experiments showed that the use of concentrations of calcium carbonate of 50.0 lb/bbl does not cause disarray in the rheological properties of the PDIP, signaling that under that optics that concentration, the development of its use in the field would not be a difficulty.
Also, results of an experimental work of treatment of the PDIF are presented with concentrations of three surfactants marks, seeking to promote mud cakes of low lift-off as an alternative method to the use of larger concentration of calcium carbonate in the fluid.
The results of those treatments with surfactants were shown to be promising. Samples of the PDIF generated mud cake of low lift-off, of same of magnitude that the mud cakes generated by synthetic fluids.
Zero Shear Viscosity Determination of Fracturing Fluids: An Essential Parameter In Proppant Transport Characterizations
Authors: Asadi Mahmoud , Conway Michael W. , Barree Robert D. 
Published: December 2007

Abstract
This paper details the importance of zero shear viscosity in proppant transport evaluation and presents a methodology to obtain zero shear viscosity of fracturing fluids. Knowledge of zero shear viscosity is a major factor in modeling and predicting proppant transport in hydraulic fractures. The importance of this factor arises from the fact that shear rate in the fracture decreases from its highest value at fracture walls to zero value at the center of the fracture. And since proppants are mostly concentrated at the center of the fracture, it is therefore, essential to know the viscosity of a fluid at that shear rate so that proppant transport capability of a fluid can be realistically evaluated. The developed methodology to measure zero shear viscosity of a fluid involves measurements of viscoelastic parameters such as viscosity and elasticity as a function of oscillatory frequency. A non-linear regression model based on Maxwell's model is then used to calculate fluid's viscosity at various relaxation times and hence zero shear viscosity. Detailed explanations and examples are also presented on the measurements of viscosity, elasticity, and relaxation time as well as the process at which zero shear viscosity is obtained.
Application of Propellant High-Energy Gas Fracturing in Gas-Injector Wells at El Furrial Field in Northern Monagas State - Venezuela
Authors: Salazar Arquimedes , Almanza Edgar , Chira Pedro , Folse Kent 
Published: December 2007

Abstract
The Furrial Field located in the Eastern Basin of Venezuela is characterized by large oil reservoirs with complex geology due to faulting and heterogeneity. To optimize oil production and oil recovery in the field, the operator, PDVSA, implemented a gas-injection project. Several wells were drilled and completed as cased-hole completions using through-tubing and casing-gun technology. However, the results obtained with the conventional perforating techniques yielded less than optimum injectivity indices, non-uniform injection profiles, and higher compression requirements on the gas injectors.
The primary damage mechanism in these completions was identified as asphaltene deposition, presenting the challenges of being able to identify the damaged zones, and then, to selectively treat them in a safe and economical method under the prevailing conditions. Another problem identified was the emulsion damage caused by the inverted mud system used during drilling operations. After review of the available perforation and stimulation methods, a propellant high-energy gas fracturing technique was selected for field trials to enhance injectivity. The propellant high-energy gas fracturing technique, although not a new technology, was the first application of this process on gas injectors in Venezuela.
This paper emphasizes the methodology used to validate the application of the propellant high-energy gas fracturing technique on gas-injection wells and the use of surfactant during propellant activation to further creating an additional stimulating effect in the formation. A computer simulator was used to design the propellant treatments and analyze the effects of generated pressures on the mechanical well configuration and wireline design. The primary benefit of propellant treatments is its capability to selectively create mild fracturing with minimal formation damage. This benefit was demonstrated with the improvements and changes obtained in the injectivity and productivity profiles.
The case histories from the Furrial field validate this technology and provide operational guidelines and results in the form of injectivity changes. Production log responses to evaluate effectiveness of selective propellant placement will demonstrate the changes in completion efficiency. The propellant high-energy fracturing technique offers a simple, cost effective, and time-saving alternative to more commonly known stimulation techniques for selective treatment of formations. The objectives of this document are to present the experience gained from applying the technique, the results obtained, and why this method was particularly beneficial to the wells included in this paper.
Through-Tubing Gravel Pack With Small Clearance: The Important Factors
Authors: Vickery E. Harold 
Published: December 2007

AbstractIn remedial situations, it is often desirable to place a large diameter screen inside of a liner or failed screen section and place gravel in the small annular space. In some situations, this will allow continued optimum production from the wellbore without the need for a costly sidetrack.In preparation for some remedial work in the North Sea, a laboratory investigation of important parameters involved with low viscosity gravel packing with small annular clearances was undertaken. Initial laboratory testing had indicated that the extremely tight clearance between the screen and the casing (approximately 0.27 inches radial clearance) caused sufficient change in the flow dynamics for premature bridging to occur even when standard water packing guidelines were followed. To alleviate this problem, further testing was performed to determine how standard practices could be modified to meet the challenge. This study included both circulating gravel packs and gravel packs conducted with no return flow. A variety of wellbore deviations, flow rates, sand concentrations, and washpipe diameters were tried to determine the relative importance of these variables.The results of these tests, a look at how these results fit with current concepts of through tubing gravel pack completions, and guidelines to assist in the design of through tubing gravel packs are presented.
Pilot Test of Limited-Entry Frac Applications on Extra-Thick-Pay and Vertical-Fracture Wells in the Massive Oil Pool
Authors: Li Yongming , Guo Jianchun , Xu Wei , Zhao Jinzhou 
Published: December 2007

Abstract
LJ oil field is a massive oil pool with vertical fracture propagation, which needs applying fracturing-stimulation treatments for commercial production. The main oil-containing pay S3 is between 150 m and 200 m without obvious barrier layers. To meet the requirement of three layer series of development, fracture height must be controlled. Formation caving test and stress test were done for thirty wells of six well units. Based on the stress profile, pilot test of limited-entry fracturing was done for twenty wells. In addition, we did pre-frac and post-frac temperature log for eight wells. Shown from stress test and temperature log, fracture height was successfully controlled. According to post-frac statistical data of twenty wells, the increasing oil for limited-entry fracturing was 3.5_104 ton.
Effect of Material Type and Size Distribution on Performance of Loss/Seepage Control Material
Authors: Pilehvari Ali A. , Nyshadham Venkata R. 
Published: December 2007

Abstract
Circulation losses have always been a serious and expensive problem to drilling industry. Even with the best drilling practices circulation losses do occur. In order to reduce such losses to acceptable level fluid Loss Control Material (LCM) or Seepage Control Material (SCM) is used.
The objectives of this study have been to evaluate and compare the performance of different LCM/SCM and determine the effect of size distribution on their performance. Twenty-four different LCM/SCM samples made of various materials and blends of material having different size distributions were tested with three different types of mud. The three mud types used were water base mud, regular oil base mud, and environmentally safe oil base (Synvert) mud. With each mud three tests were conducted, one with the base mud and two with LCM/SCM concentrations of 5 and 10 lbs/bbl. The experiments were conducted in a Permeability Plugging Apparatus (PPA) at a differential pressure of 2500 psi and 250 °F, using ceramic disks. The performance of each LCM/SCM sample was determined based on the amount of spurt loss and total fluid loss of the mud according to the recommended procedure for PPA. The experiments show that amount of fluid loss depends on the mud type, LCM/SCM material, concentration and size distribution.
This paper presents details of the experiments, the collected data and the analysis and discussion of the results obtained.
Working Together in a Contract Environment: Angsi, Larut and SSE Teluk Ramunia Experience
Authors: Ibrahim Shamsulkamal , Ason Nazri , Jahuri Mohd. Abdul Malik 
Published: December 2007

Abstract
Integration of safety programmes from different stakeholders is often a challenge. However, for Angsi and Larut field development projects' jackets fabrication, this opportunity was chosen up-front by the two operating companies, and later planned and executed in a tripartite HSE arrangement between the two parties and their common fabrication contractor. Despite facing various challenges, all the three parties were willing to work together. In some areas, they were also willing to do things differently such as introducing Safety Greeters programme and applying Safe Performance Self Analysis and Incident Prevention Observations programmes for the first time in their upstream sector of the oil and gas industry. All these gave significant positive impacts on safety during the fabrication phase of the three jackets.
Contractor Management by Integration into the Safety Management System
Authors: Sohani Sunil , Haugnaess Thor 
Published: December 2007

Abstract
As the safety culture evolves in the oil industry, it is becoming evident that long-term business success, as well as the safety performance of an organization, depends on the performance of its contractors and suppliers.
In this paper we discuss the key elements of the contractor management process as applied within the Safety Management System on Schlumberger sites. We detail the step-by-step process flow and the various management tools. We also present results of safety audits, showing the improvement in contractor management.
We conclude that managing contractor safety performance, by integrating contractors into the Safety Management System, is a forward step in the progress of the overall safety culture in the oil industry.
Experience in Integrating Occupational Health into Safety Risk Matrix
Authors: Liew Keng Cheng , Zainuddin Zainal Mubarik , Samad Abu Hasan 
Published: December 2007

Abstract
Traditionally, an occupational health risk assessment is conducted by the occupational health (OH) subject-matter-expert (SME) separately from a safety risk assessment which is often conducted by the safety SME. Occupational health risks are often not assessed in-depth in the safety, health, and environment (SHE) risk assessment, which is normally led by safety SME. One of the reasons could be that the methodology is not well defined to align the OH risks with safety risks on a common basis in the risk assessment. This is understandable as OH risk assessments are based on "what-is" exposure assessment whereas the safety risk assessments are based on "what if" scenario of probability of safety incident occurring. A common risk assessment matrix for assessing both OH and safety risks with prioritized SHE risks will enable the line management to manage these risks better.
This paper describes how the safety risk matrix's methodology is enhanced by integrating occupational health into the matrix. It also describes the experience and challenges in using the proposed SHE risk assessment matrix.
Deep Sea Ecosystems on the Equatorial African Margin: First Results of a Pluridisciplinary Environmental Programme and Discovery of Chemosynthetic Based Ecosystem
Authors: Sibuet M. , Galéron J. , Khripounoff A. , Menot L. , Olu-LeRoy K. , Durrieu J. , Miné J. 
Published: December 2007

Abstract
The environmental study initiated in 1998 by Ifremer and TotalFinaElf, in the framework of oil exploration, on the continental margin off Angola, Congo and Gabon, has been successfully implemented. Under this study, 9 long term moorings were laid out from RV le Suroît in April 2000 on three deep sites, and 38 trawling and box coring were operated from RV Thalassa in August 2000 near well stations. Subsequently in January 2001 cold seep communities were discovered during an in situ exploration using the new ROV Victor 6000 from L' Atalante.
On going studies brought already original results on the general structure of the benthic communities and on chemical characteristics of the sediment near well stations (Block 17 – 1350 m depth). A comparison of the biological and chemical data obtained between stations located at 200 m and about 10 km away from well stations showed: –No significant differences for most of the parameters from the preliminary observations,–No contamination level of aromatic hydrocarbon in the superficial sediment, but differences in barium concentrations, due to drilling mud which contaminated the sediment near the well.–Unexpected richness in organic carbon of the sediment not only in the surface but down to 15 cm,–Similarity of macrofauna density to that observed in other bathyal zones of the world, with however, a presence of macrofaunal organisms deep into the sediment, which can be explained by the high organic carbon content observed,–The absence of sessile fauna due to the fluidity of the sediment and the lack of hard substrate.
The discovery of localised rich biological communities of large bivalves and pogonophorans linked to fluid and gas emission shows that two types of ecosystems exist on that passive margins: the detritus based ecosystem is indirectly linked to photosynthetic production whereas the more localised cold seep ecosystem depend on chemosynthetic processes.
Compliance with Industrial Safety Legislation in Russia
Authors: Kozlov M. Ya. , Kozlov M. M. 
Published: December 2007

Abstract
This paper is intended to demonstrate experience gained by Halliburton Energy Services in Russia. The experience pertains to compliance with Russian safety legislation regarding hazardous industrial facilities including oil and gas facilities. The Federal Law of the Russian Federation on Industrial Safety of Hazardous Industrial Facilities, as approved by the President of the Russian Federation on July 21, 1997, determines the legal and economic basis for safe operation of hazardous facilities in Russia. This law covers all aspects of industrial safety including (1) licensing; (2) require ments for design, construction, commissioning, and operation of hazardous facilities; (3) requirements for accident investigation; (4) safety expertise; (5) liability insurance for damages; and (6) liability for non-compliance with the safety regulations. In the course of providing its services in Russia, Halliburton has demonstrated its capability to comply with all requirements of this Russian federal law. Halliburton, however, had to learn from its own mistakes; but it is now clear that Halliburton understands the law and is able to proficiently pursue its business.
Training foreign personnel about local safety regulations — irrespective of their international or national certificates — is one very important aspect in training for compliance. Another imp ortant aspect is instruction about obtaining Russian certificates and permits for any equipment used at hazardous facilities. Many Russian rules and standards are more stringent than those of Western countries. Some examples will be considered in the paper.
The findings of this paper can be effectively used by foreign companies and by exporters of equipment for hazardous oil and gas production facilities in the Russian Federation. These facilities are subject to supervision of the Federal Mining and Industrial Inspectorate of the Russian Federation.
Systematic Approach to Occupational Health and Safety in the Engineering Phase of Offshore Development Projects. Experience from the Norwegian Petroleum Activity
Authors: Zachariassen S. , Knudsen S. 
Published: December 2007

Abstract
Many employees on offshore oil and gas installations have to rely on personnel protective equipment to avoid work related diseases. This is not recognised as a proper prevention strategy. High noise levels and bad ergonomic solutions are often intimately embedded in the design of the installations. To rectify a hazardous design by technical modifications in the operating phase are difficult to achieve and expensive to perform. Occupational health and safety achievements seem not to fit well into traditional cost benefit based decision-making.
The Norwegian Petroleum Directorate (NPD) has since 1995 enforced an occupational health and safety legislation that focus in particular on a systematic approach in the planning phase of offshore development projects. The NPD has followed most of the recent offshore projects closely through audits and verifications.
The Norwegian petroleum industry has followed up the legislative initiative by developing specific standards for how to implement occupational health and safety requirements in the engineering phase.
Over the last few years we have observed substantial improvements of the engineering practice. A common understanding of requirements and structured co-operation between project management, experienced workers, design engineers and occupational health and safety experts seems to be important pre-requisites for success.
This paper will describe and discuss key elements of the Norwegian legislative basis and bring forward some of the experience gained trough project auditing and follow-up activity related to implementation of occupational health and safety requirements in the engineering phase of offshore development projects.