bluuebunny/crossref_metadata_2025_split huggingface dataset:
The Application of Particle Image Velocimetry (PIV) and Laser Doppler Velocimetry (LDV) in the Study of Drilling Bit Nozzles
Authors: Drakulic Radenko , Steiner Ivo , Grant Ian 
Published: December 2007

ABSTRACT
Two non-destructive optical methods - Particle Image Velocimetry (PIV) and Laser Doppler Velocimetry (LDV), as innovative methods in drilling process efficiency studies, were applied in velocity measurements of jets coming out of drilling bit nozzles.
Scientific papers and textbooks published on the subject contain results of the velocity distribution below a nozzle based on single-point measurements. This involved the use of Pitot tubes and Hot-wire anemometers, while LDV has only recently been introduced in jet bit studies.
Hydraulic parameters regularly monitored and calculated in drilling activities are jet velocity, hydraulic horsepower and impact force. Existing methods provide these parameters to be calculated only at the nozzle outlet. At the same time the area of important jet action, lying at the bottom of the hole and in between, is not adequately investigated. Recently developed PIV enables velocity measurements to be carried out simultaneously over the entire profile of the flow. PIV permits great range of velocities to be measured with high accuracy in various media, experimental setups and types of the flow.
In this paper a preliminary study of high jet velocities coming out from nozzles having circular, square, rectangular and elliptical openings is discussed. Testing facilities and results obtained both with PIV and LDV are presented.
Three-dimensional nozzles tested may have their application in drilling bit design, especially in PDC bits. Moreover, employed techniques allow effective evaluation of nozzles, better understanding of the high velocity jet behaviour and may significantly contribute to the optimization of drilling hydraulics. In addition, possible other applications of PIV and LDV in domain of petroleum engineering are discussed.
Gas Rises Rapidly Through Drilling Mud
Authors: Tarvin J. A. , Hamilton A. P , Gaynord P. J. , Lindsay G. D. 
Published: December 2007

ABSTRACT
To understand the development of a gas kick, we must know the rate at which gas migrates upward through drilling mud. Migration rates measured in laboratory experiments are much greater than those commonly accepted by the drilling industry. To address this controversy, we use a computer simulator to model field data and test-well experiments in detail. Both the experiments and the Held data show that gas migrates as fast as 6000 ft/hr [0.5 m/s] through drilling mud. The field data show that gas migration can drive surface pressure up as fast as 3000 psi/hr [4.9 kPa/s], These conclusions agree with laboratory experiments and contradict what is generally accepted in die industry.
The results from the simulation of the field kick were incorporated in a case study. The study increases drill crew awareness of the speed at which gas can arrive at surface and demonstrates that a reduction in pump pressure can be a very late kick indicator.
The National Advanced Drilling and Excavation Technologies (NADET) Program: A New Collaborative Research and Development Initiative
Authors: Mock J. E. , Jelacic A. J. , Dorr P. M. , Perle M. 
Published: December 2007

ABSTRACT
Geothermal energy, heat energy stored in the earth, is exploited for the generation of environmentally clean, reliable electric power and for direct heat applications such as space and water heating, aquaculture and agricultural operations, enhanced oil recovery, mining, and industrial processing. With 2800 megawatts of installed electric capacity generating 15 billion kilowatt-hours per year and 18 trillion Btu per year utilized in direct-heat applications in the U.S., expanded market penetration is often hampered by higher costs associated with geothermal energy development. A significant portion of these higher costs is directly or indirectly dependent on drilling wells to discover, delineate, and produce geothermal resources. The Geothermal Division of the U.S. Department of Energy has proposed a national R&D initiative involving government, national laboratory, industry, and academic stakeholders to develop less costly ways of penetrating rock. The goal of this proposed program is to develop an advanced and innovative drilling system by the year 2000 for use by the geothermal industry and other industry sectors including oil and gas, mining, underground storage, and civil infrastructure.
Drilling Operations, Deep Sea Drilling Project
Authors: Eberhart J.R. 
Published: December 2007

This paper was prepared for the 40th Annual California Regional Meeting of the Society of Petroleum Engineers of AIME, to be held in San Francisco, Calif., Nov. 6–7, 1969. 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 usually granted upon request to the Editor PETROLEUM ENGINEERS JOURNAL is usually 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 two SPE magazines.

Abstract
The Deep Sea Drilling project is funded by the National Science Foundation for 12.6 million dollars for a period of 18 months to carry out a deep-earth sampling program. Scripps Institution of Oceanography of the University of California is the prime contractor and operator for the project. The project's scientific objectives are to provide new knowledge of the ocean basins, provide new knowledge of the ocean basins, their history and record of changing climate and evolving life for many millions of years. Physical evidence substantiating two Physical evidence substantiating two principal geological hypothesis (sea floor, principal geological hypothesis (sea floor, spreading and continental drift) has been recovered. The operational objective is to penetrate all sediments, recover samples of penetrate all sediments, recover samples of these sediments, make a shallow penetration of the basement and recover samples of the basement.
Drilling operations in the deep ocean basin are being conducted from the Glomar Challenger to obtain core samples of the sediment and basement in water depths to 20,000'. This paper will summarize the results obtained and paper will summarize the results obtained and the drilling techniques used on the first six legs of the program. The summary includes discussions on the drill ship, dynamic positioning, drilling equipment, drill string, positioning, drilling equipment, drill string, coring equipment, techniques used to obtain the cores, electric logging and the results obtained on the first six legs of this project.
What Really Wears Your Casing When New Hardmetals Are Used?
Authors: Carlin F. J. 
Published: December 2007

ABSTRACT
Tool joint hardfacing was introduced nearly fifty years ago. The primary purpose was to prolong tool joint life by reducing outside diameter wear. Tool joint life was increased up to three times.1 The hardfacing adequately protected the tool joint but often times resulted in severe casing wear by abrasion.
The potential for casing damage resulted in the development of several improved types of hardfacing. Most prevalent are the smooth tungsten carbide type and iron base hardmetals alloyed with chromium. Test results by various manufacturers, users, and independent consultants indicate these new types of hardfacing are less abrasive than the tool joint steel. The primary type of wear for these hardfacing materials is adhesive. This change of wear mechanism from primarily abrasive to adhesive is a major reason why these hardfacing materials reduce casing wear. The surface finish is also a major contributor, since a smooth uniform finish reduces contact stress2.
Full sized casing wear tests were performed to evaluate not only the effect of the hardfacing, but the relationship between hardfacing and available tool joint tong space. Hardfacing on the tool joint outside diameter is normally three inches (76.2mm) while the remaining tong space of the tool joint pair is fourteen to eighteen inches (355.6 to 457.2mm). Most of the current available hardfacing materials were evaluated (fine particle, coarse particle, smooth tungsten carbide, machined smooth tungsten carbide, and three iron base hardmetals).
Test results indicate that when these new improved hardfacing materials are used casing wear is dramatically reduced and is significantly influenced by the steel portion of the tool joint tong space that is not hardfaced. The casing is in contact with the tool joint steel four to six times longer than the hardfacing. Since the major type of casing wear is adhesive wear for both the tool joint steel and the hardfacing material, selection of hardfacing material may be based on other criteria such as wear resistance, surface finish, ability to re-hardface, availability, price, and hole conditions.
Digitizing Rocks?: Standardizing the Process of Geological Descriptive Using Workstations
Authors: Saunders M. R. , Shields J. A. , Taylor M. R. 
Published: December 2007

ABSTRACT
The preservation of geological knowledge in a standardized digital form presents a challenge. Geological data in themselves are fuzzy. Data sources range in scale from the macroscopic, e.g., outcrop, through the mesoscopic, e.g., hand-specimen, core and sidewall core, to the microscopic, e.g., drill cuttings, thin sections, and microfossils. Each scale change results in increased heterogeneity and potentially contradictory data. Finally, the providers of such data may vary dramatically in experience level. Hence the challenge!
To address these issues, a geological description workstation has been developed for cores and drill cuttings, and has undergone field trials. Over two thousand carefully defined geological attributes are currently available within a relational database. Attributes are stored in definitive digital form, allowing multiple users to select familiar usage, e.g., diabase v. dolerite. Data can be entered in one language and retrieved in other languages. The data structure allows groupings of similar elements, e.g., rhyolites into the acidic-igneous or volcanics subgroups, or into the igneous rock group, permitting different users to analyse details appropriate to the scale of the application.
Data entry utilizes a graphical user interface, allowing the geologist to make quick, logical selections, in a standardized or custom-built format. Extensive menus, onscreen graphics and help screens allow "point-and- click" selection. Descriptive ranges, e.g., round to subrounded, are permissible. Error checking limits the potential for geological oxymorons. Entries for lithology, petrology, structures (sedimentary, organic and deformational), reservoir characteristics (porosity and hydrocarbon shows) and macrofossils are available. As data are selected and applied, the on-screen concatenated description is updated to provide immediate feedback, ensuring data correctness. Sampling points for thin-sections, core analysis, geochemistry or micropaleontology are also recorded.
Utilizing digital data storage, construction of geological logs using graphical, alpha-numeric (both abbreviated and complete words) and symbolic representations are possible. Geological descriptive data can also be combined with drilling and mud gas data, MWD and wireline logging data, and off-site analyses, to produce composite formation evaluation logs, thus enhancing the value of each data source through integrated information management.
An Efficient Procedure for the Quantification of Risk in Forecasting Reservoir Performance
Authors: Kalogerakis Nicolas 
Published: December 2007

Abstract
Once a reservoir have been satisfactorily history matched by fitting all production data taken up to the time of the study, the reservoir engineer proceeds with the computation of future reservoir performance under alternative depletion strategies. As part of this forecasting exercise a sensitivity analysis is often performed in an effort to quantify the deviation from the expected production levels should certain important reservoir parameters have a different value than that used in the history matched model. It is this uncertainty in the predicted reservoir production levels that is addressed in this manuscript. By using the statistical properties of least squares estimates, the uncertainty in all estimated reservoir parameters can be readily incorporated into the computations. The proposed methodology is illustrated with a typical example where 95% confidence intervals of individual well production rates as well as of the cumulative overall reservoir production are computed.
Risk Analysis of Well Performance: A New Approach To Optimize Well Deliverability
Authors: Johannessen Liv , Bakken Hilde , Leach P. R. L. , Tybero Geir 
Published: December 2007

Abstract
The Heidrun field, situated on the Norwegian Continental Shelf (Figure 1), is scheduled to come on stream in August 1995. Heidrun will be developed using a tension leg platform (TLP). The reserves are estimated to 119 M Sm3 (750 M STB) of oil and 45 GSm3 (1.6 TSCF) of gas. Heidrun consists of three main reservoirs, the Fangst Group, the Tilje Formation and the Are Formation where the Fangst Group contributes more than 70% of the total reserves. A total of seven Fangst oil producers will be pre-drilled and pre-completed to accelerate the build up period. These wells are all planned as gravel packed wells with high deliverability.
To optimize the completion design and maximize flowrate potential for the producers, a new approach to evaluate well performance was developed. The individual well deliverabilities were computed as a probability distribution directly reflecting the uncertainties related to the input variables rather than the more conventional single flow rate.
The results showed that the flowrate was likely to be restricted by the completion configuration rather than the reservoir deliverability. As a result, the current tubing size was increased and the Fangst well design rate was raised. By increasing the design rate, the pre-plateau period was reduced. This increased the NPV of the Heidrun project significantly.
Jet Pump Testing in Italian Heavy Oils
Authors: De Ghetto Giambattista , Riva Marco , Giunta Paolo 
Published: December 2007

Abstract
The paper presents the analysis and the results of the jet pump applications in the two biggest Italian heavy oil fields: Vega (15 °API) in offshore Sicily and Gela (9 °API) in onshore Sicily.
In both fields the water cut is as much as 50% and most of the wells produce in artifiCial lifting: ESP, diluent lift and rod pumps are the three methods used.
The tests with jet pumps were motivated by the need to use a cheaper artificial lifting method. The objective was, in fact, to reduce both the workover costs for replacing the failed pumps and the operating costs of the wells producing in diluent lifting.
Various jet pumps sizes, types and rate of the power fluids were experienced.
Accurate measurements of the pressure above and below the jet pumps were recorded allowing comparison of the field performance with the theoretical one.
The field test campaign finished in 1991/1992 and demonstrated that the jet pump, despite its low efficiency ( 30 - 60 % lower than expected ) and flexibility, is an efficient and cost-effective way to produce heavy oils.
The jet pump installation costs, in four wells, have been 6-9 times less than workover costs for replacing ESP.
We deem that the conclusions of the study can be useful also in the application of jet pumping in other heavy oil fields.
Value of Subsea Standardised Systems
Authors: Knudsen T. W. , Lindland H. J. 
Published: December 2007

Abstract
This paper reviews Statoil’s experience with standardisation of its subsea field developments, service and tool pool arrangements for several subsea fields and future plans for deep water applications. Aspects of maintaining standard specifications in a rapidly developing area of technology are discussed. Subsea standardisation, applied at the appropriate system design level and agreed with potential suppliers, will contribute to the economic development of marginal fields. Statoil’s strategy on how to adapt and integrate multiphase production systems into the architecture of its existing standardised systems and future deepwater field developments is also presented.
As used in this paper, the term "standardised system" reflects an established subsea pool standard.
Standardisation does not mean that every project should be exactly the same. Nevertheless, similar projects should work to a standard specification, with standard designs for interfacing completions, workover-riser systems and intervention systems.
A Comparative Technical and Economic Analysis of Waterflood Infill Drilling and CO2 Flood in West Texas Carbonate Reservoirs
Authors: Guoping Xue , Malik Z. A. , Wu C. H. , Mamora D. D. 
Published: December 2007

ABSTRACT
Waterflood infill drilling and C02 flood have been used to improve oil recovery from West Texas Carbonate reservoirs. This paper presents a comparative study of technical and economic analysis of waterflood infill drilling and CO2 flood in the Monahans (Clearfork) unit and Johnson J.L. 'AB' (Grayburg/San Andres) unit. Decline curve analysis is used to estimate the recovery efficiencies for different well spacings. An analogous study for West Texas reservoirs is used to estimate the C02 flood recovery. With waterflood infill drilling at IO-acre spacing, the recovery efficiency is estimated to improve to as high as 30% OOIP. However, economic analysis indicates that waterflood on a 10-acre well spacing is less profitable (ROR 8%) when compared to C02 flood (ROR 17%).
Pre-Production Pressure Analysis of Commingled Reservoir with Unequal Initial Pressures
Authors: Aly Ahmed , Chen Her-Yuan , Lee W. J. 
Published: December 2007

ABSTRACT
This paper examines the effect of unequal initial layer pressures on the pressure and sandface rate responses of wells producing from commingled reservoirs. The main objective is to provide techniques and methodology to determine individual layer permeabilities and skin factors in commingled reservoirs with unequal initial pressures. The layer information obtained early in the life of the reservoir is very important for planing production schedule and economic decisions concerning the future of the wells.
The emphasis of this research is on the study of the wellbore performance during pre-production which is the period after completion but before any production on surface. The results of this study provide a useful foundation for the design of well test procedures to ensure that individual layer properties are measured adequately. As the pre-production well test requires no production on the surface, the environmental impact caused by flaring oil or gas during a conventional well test is alleviated.
Evaluation of Paraffin-Treating Programs in Rod-Pumped Oil Wells
Authors: Henson R. D. , Tangen T. J. , Horne P. T. 
Published: December 2007

ABSTRACT
This paper will convey a philosophy of managing a paraffin program. The philosophy developed is a closed loop system which includes data collection, treatment selection, and performance evaluation. The key to a successful program is maintaining a focus on the problem.
The Denver Unit CO2 Flood Transforms Former Waterflood Injectors Into Oil Producers
Authors: Fox C. E. , Tugwell J. O. , Morell J. I. 
Published: December 2007

ABSTRACT
The profitable conversion of off pattern water injectors to production wells is possible in CO2 floods. An initial water production period often precedes the breakthrough of oil into such injector-to-producer (ITP) conversions. At the Wasson (San Andres) Denver Unit in West Texas, time to economic oil production and initial economic oil production rates may be estimated by simulation or analog methods. Performance data from more than 25 wells is discussed in this paper.
Quantifying Skin Damage and Improvement in Horizontal Wells
Authors: Malekzadeh Dariush , Abdelgawad A. S. , Day J. J. 
Published: December 2007

AbstractThe potential for severe formation damage around horizontal wells exists due to the increased time of formation exposure to the drilling fluids as compared to the time that a vertical well is exposed to these fluids. This paper explains that the combined effect of the formation damage and the presence of impermeable barriers and low permeability regions in the vicinity of some sections of the horizontal wellbore will manifest itself as skin factor in well test analysis if the total drilled length of the horizontal section is used in the calculations. The purpose of this paper is to present practical new equations, based on a recently introduced concept in well performance analysis, for evaluating the effective length of the horizontal well contributing to unrestricted production. It is determined that the performance of a horizontal well with mechanical skin and of length Xf1 can be substituted by the performance of a horizontal well of length Xf2 with no skin. Xf2 is smaller than Xf1 for a damaged well and is greater than Xf1 for a stimulated well. By combining the concepts of equivalent horizontal well length and equivalent wellbore radius, one will be able to evaluate the performance of a horizontal well in comparison to its expected performance and to subsequently relate it to an equivalent stimulated vertical well. The new equations and guidelines can be used to determine the magnitude of formation damage around horizontal wells and to evaluate the success of a stimulation treatment.The concept of effective horizontal well length developed in this paper was applied to the pressure drawdown analysis of well test data obtained on a horizontal well. A good match was obtained which were used to calculate the parameters of interest. Furthermore, the productivity index for this horizontal well was determined using the newly developed equation.
New Technique of Fracture Stimulating the Morrow and the Atoka Formations of Southeastern New Mexico
Authors: Pai V. J. , Keith M. M. , Edgeman Randall , Hust Pete 
Published: December 2007

Abstract
With improved gas pricing the Morrow and the Atoka formations of S.E. New Mexico are seeing substantial amounts of renewed activity. The paper presents background information such as lithology, formation properties obtained from X-Ray Diffraction and SEM Analysis and rock properties obtained from other sources. Casing and perforating programs along with completion and stimulation practices are also discussed. The paper lays emphasis on the recent use of the Binary Foam as a fracturing fluid along with case studies.
Additionally, the paper goes over the design of a Binary foam frac with the aid of 3-D design model and foam fluid rheology. Post frac productivity results along with the amount of proppant placed in the fracture are presented to help in future frac designs.