bluuebunny/crossref_metadata_2025_split huggingface dataset:
Use of Drilling Parameters for Planning Effective Payzone Isolation
Authors: Rodríguez W. , Garcia M. , Pestana D. 
Published: December 2007

Abstract
The present job is a methodology to systematize the cementing job operation based on drilling information in order to define slurries, preflushes and procedure for planning, execution, controlling and evaluation of cementing job.
Difficult geometry, high deviated angle, shallow and deep gas wells, gelled mud and oil based mud are some of the harsh environments where this methodology has been used successfully.
Results show excellent zone isolation of Payzone and their impact on drilling.
Environmental Management, Cost Management, and Asset Management for High-Volume Oil Field Waste Injection Projects
Authors: Bruno Michael , Reed Alex , Olmstead Susanne 
Published: December 2007

Abstract
Ongoing exploration and production activity, combined with increased regulatory requirements, are increasing the volume and costs associated with disposal of oil field wastes, including produced oily sands and tank bottoms, drilling mud and cuttings, crude contaminated surface soils, and naturally occurring radioactive materials (NORM). A cost-effective and environmentally sound disposal option is to re-inject waste material into the subsurface into non-productive and/or depleted zones under controlled fracture conditions.
High volume injection projects often involve annual injection exceeding several hundred thousand barrels of waste for several years. The critical engineering management goals for such operations are to:
Maintain waste containment in the target formation (environmental management); Sustain long-term injectivity with minimum equipment repairs and well workovers (cost management); and Maximize formation storage capacity and well life (asset management).
More than five years experience operating, analyzing, and managing large volume waste injection projects in the US and Canada has enabled Terralog to develop specific design, monitoring, and operating strategies to achieve these goals. Target injection formations must be selected with appropriate overlying barrier and absorption zones. Offset well completions must be carefully examined. The injection well completion should be appropriately designed to take into account high formation stresses and potential movement. Continuous monitoring and analysis must be performed to evaluate varying formation properties, injectivity, stress conditions, and fracture orientation and height growth. Finally, through continuous monitoring and analysis of formation response, injection parameters and properties (such as solids concentration, density, flow rate, shut-in time, etc…) can be adjusted in order to maintain containment, reduce operating costs, and optimize long-term injectivity.
Successful Application of a Novel Fracturing Fluid in the Burgos Basin, Mexico
Authors: Centurion Sergio , Alcantar Manuel Silva , Rascon Austreberto Rios , Ortega Aaron Torres 
Published: December 2007

Abstract
The only way to obtain an optimum production in the wells that form the Burgos basin in the north of Mexico is using the hydraulic fracturing technique.
This paper describes how was the evolution of fracture fluid since 1996 till now, based mainly on each stimulated zone's depth and temperature.
A new frac fluid, whose main characteristic is the low polymer load used to stimulate moderate to high temperature wells, was introduced within a process of optimization performed by Petroleos Mexicanos.
The detailed information here can be useful for future hydraulic fracture treatments to be performed in this zone.
On the other hand, a typical case was analyzed using a fracture simulator linked to a production simulator. A comparison of the production result using two fluids (a conventional one and a low polymer load new one) was made.
The advantage of the production company when using this new technology in fracture fluid was determined.
Three-Phase Immiscible WAG Injection: Micromodel Experiments and Network Models
Authors: Larsen J. K. , Bech N. , Winter A. 
Published: December 2007

Abstract
This paper is concerned with planning and optimization of three-phase immiscible Water-Alternating-Gas (WAG) injection processes. This goal is achieved by applying an iterative procedure linking the pore-level displacement mechanisms with a macroscopically defined WAG process.
Alkali / Surfactant / Polymer at VLA 6/9/21 Field in Maracaibo Lake: Experimental Results and Pilot Project Design
Authors: Manrique E. , De Carvajal G. , Anselmi L. , Romero C. , Chacón L. 
Published: December 2007

Abstract
The VLA 6/9/21 Field is a waterflooded light crude oil reservoir located in Maracaibo Lake, West Venezuela. In the last two years PDVSA E & P has developed Integrated Laboratory Fields (ILF) as a strategy to evaluate new technologies and EOR methods in order to improve light and medium oil recovery factors. Alkali/Surfactant/Polymer (ASP) is one of the chemical flooding technologies that has recently been evaluated in Venezuela.
The objetive of this study is to describe the followed methodology to develop ASP formulas, describe the pilot test planned for this year and also to determine whether ASP technology can produce incremental oil in the Eocene C-4 Unit of VLA 6/9/21 Field economically. The study was performed at reservoir temperature of 90°C with dead crude oil and rock sandstones from the oil producing zone located in the pilot area.
Several ASP formulas were developed for the VLA 6/9/21 Field with comercial petroleum sulfonates. Each ASP solution gave interfacial tension (IFT) values below 9x10−3 dynes/cm. Rheologic studies with polyacrylamide polymers using different additives indicate that the solution viscosity can be mantained over the time at least 2 cp above the crude oil viscosity (2,5 cP) at reservoir temperature. Surfactants, alkali and polymer retention were below 0,08 mg/g rock. Incremental oil recoveries were higher than waterflood, obtaining recoveries between 22 and 39% OOIP for 0,3 PV ASP and 0,15 PV polymer injection in reservoir cores. The positive results of this laboratory study provided an ASP formula for a pilot test supported with the injection of oil partitioning tracers before and after the chemical additives as part of one of the ILF of PDVSA E & P.
Reservoir Characterization and Laboratory Studies Assessing Improve Oil Recovery Methods for the Teague-Blinebry Field
Authors: Svec Robert K. , Grigg Reid B. 
Published: December 2007

Abstract
A study to review previous work, perform additional laboratory tests, and identify pay from well logs in the Teague-Blinebry field was performed at the New Mexico Petroleum Recovery Research Center (PRRC) a division of New Mexico Institute of Mining and Technology. Recovered core from one well and well logs from across the field were evaluated. Laboratory results included:
Mineralogy, fracture systems, and oil stains were described for 251 ft of recovered core. Slabbed core scanning minipermeametry were performed on 79 samples, air permeabilities on both ends of twelve plugs, brine permeabilities on two samples, and water and carbon dioxide (CO2) floods on two samples. Minimum miscibility pressure was determined to be the higher of 1010 psig or the system bubble point pressure. Wettability index was determined to be ‒0.608.
Core permeability measurements identified very low matrix permeability in the Blinebry dolomite. Regions of conductive vugs and fractures were detected. Tests indicate that even apparently filled fractures play a significant role in fluid movement. This observation is supported by effective permeability results, derived from step rate tests, of 1.15 md; well above the average matrix permeability.
Density/neutron and induction or laterologs were used to identify pay in 16 wells with modern log suites. In order to include a greater number of wells, a procedure was adopted in which field average parameters were used with 47 sonic porosity logs from the older wells lacking density/neutron data. Net pay and original oil in place were calculated for 63 wells. Targets for potential water or CO2 flood development are identified as the upper one-third of the Blinebry.
Historical Use of m and a in Well Log Interpretation: Is Conventional Wisdom Backwards?
Authors: Adisoemarta P. S. , Anderson G. A. , Frailey S. M. , Asquith G. B. 
Published: December 2007

Abstract
Archie's laboratory experiments established a relationship between the formation resistivity factor and porosity, which set forth the use of two constants: m and a. From Archie's work these constants were regression constants representing the slope and intercept, respectively. Subsequent researchers used the general form of Archie's relation, but they found differing values for m and a. The terms cementation factor and tortuosity factor have been used to describe each of these terms. Conventional wisdom believes that a higher m relates to vuggy porosity and a lower m suggests fracture porosity. This is generally true if the tortuosity factor is assumed (typically 0.81 or 1.0) and the cementation factor is calculated.
However, if m and a are found simultaneously, theory and many laboratory observations suggest the opposite may be more likely. This study shows that the tortuosity factor, a, is a function of the average angle of electrical movement with respect to the bulk fluid flow, and cementation factor m is related to the flow area contrast between pore throat and pore body.
Diagnostic Techniques to Understand Hydraulic Fracturing: What? Why? and How?
Authors: Cipolla C. L. , Wright C. A. 
Published: December 2007

Abstract
In recent years there have been numerous advances in fracture mapping/diagnostic technologies. This paper details the state-of-the-art in applying both conventional and advanced technologies to better understand hydraulic fracturing and improve treatment designs. The initial portion of the paper describes the application and limitations of various diagnostic tools and methods, including well testing, net pressure analysis (fracture modeling), techniques that employ open-hole & cased-hole logs, surface & downhole tilt fracture mapping, microseismic fracture mapping, and production data analysis. The bulk of the paper is dedicated to case histories that illustrate the application of these various fracture diagnostic technologies. The case histories include examples of how several fracture diagnostics can be used in concert to provide more reliable estimates of fracture dimensions and allow better economic decisions.
Production Optimization of Gas Wells by Automated Unloading: Case Histories
Authors: Foo David B. 
Published: December 2007

Abstract
This paper documents attempts to automatically unload gas wells in the Western Sedimentary Basin at various depths and producing conditions. The results include production increases of 25%, with reduced operating costs. The criteria for application of this technology and a cost/benefit analysis are presented. This work is being incorporated in a large-scale project currently underway in Oklahoma, which will be discussed briefly as an example of integrating automation technology with expert systems to provide field-wide optimization of a major gas field.
Experimental Investigation on the Rheology of Foams
Authors: Bonilla Luis Fernando , Shah Subhash N. 
Published: December 2007

Abstract
In this study, the rheology of foams was investigated using aqueous foams and gelled foams and employing a pipe type viscometer. Water was used as the liquid phase for the aqueous foams while guar was used as the gelling agent for the gelled foams. Surfactant at 0.5% (vol.) concentration was used as the foaming agent. The flow data showed that foams behave like Herschel-Bulkley model fluids.
New empirical correlations have been developed from the experimental data to predict foam fluid apparent viscosity. These correlations are function of liquid phase properties and foam quality and are applicable to the foam systems tested in the wide range of shear rates and temperatures investigated. The use of these new correlations will provide more accurate estimation of the foam fluid rheological properties.
Development of Gas-Condensate Reservoirs by Directional Intracontour Waterflooding
Authors: Berman L. , Ryzhik V. , Mirotchnik K. , Allsopp K. 
Published: December 2007

Abstract
This paper presents an overview of some of the advanced water-flooding technologies developed for gas-condensate reservoirs (GCR) in the former Soviet Union. Although developed in the 1970's and since then successfully applied in the field, there are no published accounts of this technology being applied elsewhere.
This technology is based on both the block structure of most gas-condensate reservoirs and the " block reservoir structure" of major fields. In both case areas of low permeability connect seemingly separate reservoirs or field zones. These areas of low permeability act in a manner similar to semi-permeable membranes. The flow of water through low permeability areas, especially those containing clay deposits, takes place only if the pressure gradient exceeds some initial value (initial gradient). Such phenomenon also occurs for gas flow, but the values of the initial pressure gradient for gas (Gg) are much lower than for water. As a result, injected water cannot flow through these areas of low permeability and move from one highly-permeable zone to another. However, at the same time gas can flow freely from block to block provided the pressure gradient is higher than Ggi. The properties of gas-saturated rocks prevent water invasion into the "dry" blocks, until the blocks with injection wells are almost totally saturated by water (at Sgres). By utilizing this phenomena, greater gas and condensate recoveries can be achieved than by using water injection schemes which disregard the intrinsic heterogeneity of reservoirs.
An experimental laboratory program verifying the phenomenon of initial pressure gradient was performed in the TIPM Laboratory in 1999. This work is ongoing.
Automation System Case Study of Coalbed-Methane Development
Authors: Robertson Steve K. , Pool Mike , Farrens Michael J. , Butts Tammie J. 
Published: December 2007

Abstract
Can an independent producer fulfill a vision to develop and produce a coalbed methane gas field that covers two hundred square miles in a remote desert plateau in the western United States? This paper will answer that question as well as provide answers to other pertinent questions, such as, "What tools would be available to the operator to efficiently and safely produce the wells?" And, "Would the tools allow for future expansion and/or allow new technologies to be incorporated into the system cost-effectively?"
This case study will show how River Gas Corporation was able to successfully meet their needs with an automation system that was jointly developed with an engineering/ manufacturing company. All phases of the project, from its inception in 1991 with a 13-well pilot project to a planned 600-well development will be discussed. Innovative solutions successfully answered the above questions and allowed the system to evolve to meet the continuing changes in expansion and production needs.
Evaluation of Acid Treatments in Horizontal Wells
Authors: Zhu D. , Hill A. D. , Looney M. D. 
Published: December 2007

Abstract
Acidizing is often applied in horizontal wells to improve well performance. Acidizing in horizontal wells differs significantly from the acidizing of vertical wells. The length of acid contact is much longer, the formation properties over the contact length likely vary in a larger range, and the cost is generally higher. To enhance the effectiveness of matrix stimulation, methods to evaluate and optimize acid treatments similar to those used for vertical wells can be adopted for horizontal wells.
This paper introduces a simple approach to evaluate horizontal well response to acid treatments. Skin factor was calculated explicitly in the method from pressure and flow rate, which can be directly measured during a treatment. Skin factor is then used to identify the well response to acid injection, and therefore to understand and control the stimulation process. There have been several mathematical models published to simulate the pressure/flow rate behavior of horizontal wells. Most of them have complicated solutions and have to be solved numerically. We selected and modified analytical solutions for horizontal well performance that can be implemented for field evaluation of acid treatments.
Field examples presented in the paper show how to apply the evaluation method for horizontal wells. The method can assess the effectiveness of acid treatments and can be used to optimize subsequent treatments.
Encapsulated Scale Inhibitor Treatments experience in the Ghawar Field, Saudi Arabia
Authors: Hsu J. F. , Al-Zain A. K. , Raju K. U. , Henderson A. P. 
Published: December 2007

Abstract
An alternative scale inhibition method using encapsulated scale inhibitor has been successfully used to control calcium carbonate scaling in the Ghawar Field oil wells of Saudi Aramco, Saudi Arabia. Field tests indicate that the Ghawar Field requires a low threshold scale inhibitor concentration for scale mitigation. The encapsulated phosphonate scale inhibitor treatment procedure is thus ideally suitable for scale control in such fields. Since 1994, a total of 89 wells have been treated with this procedure. After more than five years of treatment, there has been no reappearance of scale deposit on the treated wells except for two instances of scaling. Low treatment cost and the resulting long treatment life have provided an excellent incentive to treat more wet producers using the encapsulated scale inhibitor treatment method instead of treatment by conventional scale inhibitor squeezes. An additional benefit is realized from this encapsulated inhibitor method when treating marginal high water cut wells and wells located in low pressure areas by ensuring that the wells sustain flow after the treatments without the need for extensive livening work.
This paper presents the results of a field case study where calcium carbonate scaling was controlled using the encapsulated scale inhibitor treatment procedure. Treatment design, job procedure, inhibitor return monitoring, economic analysis and comparison with conventional squeeze treatments as well as future applications are presented.
Health-The Forgotten Element: The Workers Perspective
Authors: Stephenson C. D. , Molloy J. K. 
Published: December 2007

Abstract
HSE, Health, Safety and the Environment. These three elements dominate virtually everything we do in offshore operations around the UK, and indeed around the world. But do they? ‘Safety is Priority’. At local, national and international levels, there are new initiatives being rolled out on a regular basis aimed at reducing incident and accident rates. Acknowledgement of issues such as global warming, and a greater awareness of our fauna and flora across the globe, has heightened awareness on the environmental front. But what of health? We believe that health issues are lost in the drive to address safety statistics. Not physical health, there are countless initiatives on healthy eating, exercise etc. No, mental health. The stress factors faced by an ever increasing number of workers across the industry is, in our opinion, impacting on the other elements of Safety and the Environment.
In recent years the UK sector has seen a sharp increase in the number of fatalities, major injuries and incidents. Why? Industry tells us that the greater percentages are attributable to human error.i The same is said when incidents are of an environmental nature. But why are we having so many human failures? Highly skilled, highly motivated, intelligent workers making so many mistakes? Victimisation, discrimination, harassment, disillusionment, depression, all have a psychological effect on workers. All are present in the UK industry today. All of them breed an attitude, a mindset, a ‘culture’ amongst workers. We hear so much about creating a ‘safety culture’, yet fail to see the problem.
The only objective measure of ‘culture’ is in studying what people do as opposed to what they say. What the industry is currently saying differs greatly from what they are actually doing, and we will demonstrate this through practical example.
Fitness to Work: Computer Assisted Health & Fitness Assessment
Authors: Keech J. , Steele C. 
Published: December 2007

Abstract
A computer assisted health and fitness assessment process has been used for five years in a major North Sea operator. The system is used to establish fitness to work especially offshore. The process has raised the profile of health, engaged the workforce in health improvement. It is cost effective and empowering for the health staff. The data generated is a major source of information about an offshore workforce.
A Step Change in Safety
Authors: Williams S. , Carroll D. , Thomson A. , Watkins G. 
Published: December 2007

AbstractThis paper outlines the setting-up and progress of a cross-industry initiative to bring about a step change in safety.The ‘Step Change in Safety’ initiative was launched in 1997. It was based on a commitment by leaders from UKOOA, IADC and OCA to deliver a 50% improvement in safety performance over three years.A strategy was embarked on to:demonstrate the commitment of the industry leaders develop greater cross-industry co-operation for sharing and learning good practice engage and involve all people employed in the industry in the improvement process.This paper details the stages of development of the ‘Step Change in Safety’ initiative, the achievements that have been made and the challenges for the future. In particular, it introduces the Safety Culture Maturity Model and Safety Culture Improvement Process developed by a behavioural issues task group.Details of the work of some of the Step Change task groups are described in other papers presented at this conference1,2,3,4,5.