bluuebunny/crossref_metadata_2025_split huggingface dataset:
IFP's Computerized Optimization System for Turbodrilling
Authors: Gosselin J.C. 
Published: December 2007

Abstract
During the drilling process the down-the-hole drilling rate may be quite different from the surface feeding speed due to drill pipe elasticity. In turbodrilling, for example, the turbodrill may stick in the hole bottom while pipes are still being fed at the surface with no other result than an increase in the weight on the bit. Conversely, when the pipe feed is arrested at the surface the bit may "drill off."
An accurate measurement of the down-the-hole drilling rate has been developed and success fully tested by the IFP. The system includes a real time computer which calculates the mean value of the drilling rate for each cycle of the mud pump. This computerized drilling rate is thus valuable in both continuous and transient movement.
Knowledge of the down-the-hole drilling rate makes possible an automatic real time optimization of the turbodrilling process. This optimization is based on the fact that the drilling speed passes through a maximum for a certain value of the weight on the bit.
In the automatism developed by the IFP the weight on the bit is slightly increased and decreased in alternation so that its mean approximates an optimum value. This turbo-drilling optimization was conceived, developed and tested with the help of the IFP's experimental "flexodrilling" rig. Results obtained in December 1970 seem very encouraging and indicate future adaptability to more conventional turbodrilling with rigid pipes.
Optimisation of the drilling rate may not, however, be enough to ensure optimization of the drilling cost which obviously should be the ultimate goal. When turbodrilling with diamond bits whose footage is very high, optimization of drilling rate would of necessity result in optimization of drilling cost. On the contrary, when drilling with tricone rock bits, the rate of bit wear and tripping costs must be taken into account in order to ensure a minimal drilling cost. This involves continuous measurement of the degree of bit wear—easily accomplished in flexodrilling but very difficult in the case of conventional turbo-drilling.
Remote Drilling Operations Offshore Sakhalin Island, Russia
Authors: O’Meara J. E. , Yarwood D. J. , Mandel A. Y. 
Published: December 2007

Abstract
This paper reviews an operator's experience in drilling two offshore wells in Russia in 1992. The wells were drilled using a Russian rig and services with the exception of electric logging, cementing chemicals, drilling fluids, and testing. Some unique inroads were made in contracting and logistics. This paper identifies the Russian and western services and materials used to drill these wells, the problems encountered in conducting the operations, and the cooperative effort established between the operator and the Russian contractor.
Chad: Remote Drilling Operations
Authors: Eads R. W. 
Published: December 2007

Abstract
Chad is a central African country stretching over 1450 kms long and 450 kms wide and is remotely situated in regard to proximity to any significant industrial / commercial centers. The country is landlocked and bordered by six other African countries. It is a sparsely populated country with approximately 6 million people. The economy is agricultural based and has limited infrastructure to support heavy industries. The remoteness of the area has created special challenges for hydrocarbon exploration since this work began in the 1970's. The country is split into essentially two climatic zones, desert climate of the barren Sahara in the north and a sub-Saharan savannah in the south with dry and rainy seasons. In the south the rainy season stretches from June through October and, due to the veiy heavy monsoon rains, is a significant factor in executing drilling operations.
Esso Exploration and Production Chad, Inc. has been active in exploration and appraisal activities in Chad since 1984, shooting 12,500 kms of seismic and drilling 24 wells. This paper will discuss the performance of several drilling campaigns in Chad and highlight the various other challenges such as logistics, security, work force safety, and medical/health aspects of the operation that consume as much, and sometimes more, effort than the drilling itself.
Using a Temporary Semi-Submersible MODU, the Ocean Voyager, on a Pre-Laid Floating Production Facility Mooring
Authors: Ettle R. E. , Bamber P. J. , Dove P. G. S. , Wilson H. 
Published: December 2007

Abstract
A large, independent Operator drilled three discovery wells and installed a 24 well template at Garden Banks 388. Two 12 inch pipelines were laid to the location. The Operator also designed a Floating Production Facility (FPF) which consisted of an Ocean Victory class senli-submersible moored to a permanent* 12 leg, catenary mooring system. The FPF conversion, due for completion in January, 1995, fell behind schedule. The Operator desired to stay as close to schedule as possible by temporarily substituting a semi-submersible drilling unit to complete the discovery Wells and tieing them back to the 24 well template.
Each pre-laid mooring leg consisted of a 25 metric ton anchor, a spiral-strand ground wire, a dip-zone chain, a spiral-strand catenary wire, and a submersible buoy assembly. First, laying additional mooring legs between the twelve pre-laid legs was considered. This was ruled out because of the danger of tangling mooring legs and damaging the relatively fragile spiral-strand construction wire ropes in the pre-laid mooring legs. Second, mooring a semi-submersible MODU to the existing pre-laid mooring legs was evaluated and selected. The MODU Ocean Voyager, similar to the FPF prior to conversion, was used. One advantage of using the pre-laid moOrings and a similar unit was that the hook-up and disconnect procedures could be tested prior to the arrival of the FPF. These procedures were refined considerably.
The initial hook-up was completed in December, 1994. Two similar 6140 BHP anchor-handling, towing, supply (AHTS) vessels were rigged with an additional two drum winch and a shallow-depth, diving spread to connect the legs. Four of the pre-laid mooring legs were left idle. Despite some difficulties, the hook-up was completed in nine and one-half days which included four days of weather delay. Disconnecting the moorings was completed in May, 1995. A single AHTS vessel was rigged with an additional two drum winch and a large A-frame over the stern* Because Of the revised procedures, considerably less diving was required. Using only one AHTS vessel further reduced costs and required only seven days, including two days of weather delay, to disconnect the moorings.
Using the temporary semi-submersible MODU allowed the Operator to complete and test two wells and connect the wells to the template with jumpers. Thus, although the FPF arrived five months late, getting production on stream should be only two months behind schedule.
Well Control Experiments related to Slim Hole Drilling
Authors: Steine O.G. , Rommetveit R. , Maglione R. , Sagot A. 
Published: December 2007

Well Control Experiments related to Slim Hole Drilling.

Abstract
During June 1994 slim hole well control experiments were performed in an inclined onshore research well in Stavanger, Norway. The tests were gas kick, annular pressure loss and surge/swab experiments.
A total number of 36 kicks were performed during these experiments. In addition we did flow tests circulating the well at various flow rates with and without rotation. The pressure loss effects of rotation on flow were logged. Tests in both plain drilling water and muds were done. Surge and swab pressures were logged downhole when reciprocating drill pipe at various tripping speeds.
Raw data files containing approx. 110 Mbytes in ASCII files of downhole pressure data, and surface data have been gathered for further analysis. The data was of high quality and provide opportunities to improve existing well control procedures and to incorporate this knowledge into future drilling operations.
This paper summarises the experimental conditions during which data were recorded, main results and some operational recommendations.
Experimental parameters such as influx type (liquid/gas), gas concentration, kick injection rate, mud flow rate, drillstring rotation rate, pipe reciprocation etc. were varied. Three kick detection systems and one flow meter were tested during the experiments.

Introduction
Well control is very critical during slim hole drilling, due to the importance of the annulus pressure loss as well as the small mud volume in the well.
Operations like pipe rotation, reciprocation, tripping etc. may generate high transient pressures in the well. Unwanted influxes and fractures may be initiated also.
The effect of rotation on the frictional pressure loss in an annulus has been studied experimentally.
Well control and hydraulics have been studied experimentally in full scale previously. An experimental programme for studying annular pressure losses and surge-swab pressures in oil based muds has been performed. Full scale kick experiments in both OBM and WBM in an inclined research well have also been reported. Experiments to validate kick control and pressure loss predictions have been performed in a slim hole test well. Tests related to continuous coring has also been reported.
A number of well control issues for slim hole drilling have been studied experimentally in a full scale research well. The well, which is 2020 m long with 63 deviation, was heavily instrumented both on surface and downhole.
P. 101
Application of High Pressure Dual Tubingless Completions and Low Cost Concepts in an Environmentally Sensitive Area
Authors: Holub Leo D. 
Published: December 2007

Abstract
Maximizing project economics through reduced drilling and completion costs is a major industry goal that challenges us for innovative ideas and risk consideration. Presented is a case history of the application of dual tubingless completions for high pressure Wilcox formations that require fracture stimulation. Low cost modem approaches to design and selection of equipment and services as well as associated risks are discussed. The project area is located in a residential housing development in a major city and also penetrates a sensitive subsurface gas storage operation. The project was highly successful without any loss to safety or the environment.
Coiled Tubing Window Milling
Authors: Hearn D. D. , Blount C. G. , Kamlowsky P. E. 
Published: December 2007

Abstract
Reliable, low cost coiled tubing window milling technology has become the cornerstone of ARCO Alaska's coiled tubing sidetrack program at Prudhoe Bay. ARCO began to investigate coiled tubing drilling technology in 1989. The program grew into an aggressive field application of this technology, with over thirty wells drilled in the last 2 1/2 years. The program's first window was cut below production tubing with a coiled tubing bottom hole assembly (BHA) in the fall of 1994. To date, 14 wells have been sidetracked using this technique.
The windows are cut off of a specifically formulated cement plug without the use of a whipstock. Reliability, always high, has continued to improve, while the cost and time required continue to come down. ARCO has been able to reduce sidetrack costs by an average of 40% compared to conventional sidetrack methods through the continued evolution of coiled tubing drilling technology, of which window milling is a part1. This window milling technique should also have the potential to save time and money in slim hole and conventional drilling applications as well.
Jack-Up Diverterless Drilling—The East Kalimantan Experience
Authors: Doré E. E. , Vlack R. L. 
Published: December 2007

Abstract
A surface hole diverterless drilling method, utilized on a jack-up drilling unit, has been successfully implemented offshore East Kalimantan, Indonesia. Variations of the diverterless drilling method have also been utilized on 72 wells drilled from platform and floating drilling units offshore East Kalimantan. The diverterless drilling method provides an enhanced risk management tool superior to conventional offshore surfacc hole drilling. This method maximizes personnel safely and minimizes risk to property and the environment. The method also provides an ancillary cost savings. The evolution of the diverterless drilling method, the practical application for jack-up implementation and the benefits of diverterless drilling are detailed herein.
A Study of Polymer Solution Rheology, Flow Behavior, and Oil Displacement Processes
Authors: Nouri Hossein H. , Root Paul J. 
Published: December 2007

Abstract
Flow and displacement theories for non-Newtonian polymer solutions in porous media have not been advanced to porous media have not been advanced to nearly the extent as those for the Newtonian fluids. At present, the field and experimental data available pertaining to the flow mechanism of pertaining to the flow mechanism of polymer solutions through porous media, polymer solutions through porous media, albeit reliable, are not comprehensive nor complete. Both experimental and theoretical research in development of a more satisfactory theory to describe the flow behavior of polymer solutions in porous media are urgently needed.
Laboratory experiments were performed to study the role of mobility performed to study the role of mobility ratio for a process in which oil is displaced from a porous medium by a polymer solution. A reduced friction polymer solution. A reduced friction factor-Reynolds number correlation is developed to predict the flow of various polymer solutions through consolidated porous media and a theory is advanced to explain more truly the flow behavior of a polymer solution as it passes through the cores.
The cone and plate viscometer data obtained for a total of 88 solutions of twelve different polymers more frequently used by the petroleum industry appeared to fit the power law equation quite well. The effects on solution viscosity of temperature, sodium chloride concentration, polymer molecular weight and polymer concentration are also discussed.

Introduction
Among the methods of secondary recovery which have been developed is one which involves the injection of high-viscosity water into the reservoir to improve the mobility ratio and thereby increase the displacement efficiency. The mobility ratio, when two immisicible fluids displace each other, is defined as the ratio of the mobility of the displacing fluid to that of the displaced fluid:
displacing M = (1)displaced
The mobility ratio is a very important factor in secondary recovery predictions, governing the recovery efficiency of the oil by the displacing fluid. A mobility ratio of greater than one will result in an uneven and an inefficient displacement and a poor oil recovery.
Effect of Specimen Size on Rock Properties
Authors: Singh Madan M. , Huck Peter J. 
Published: December 2007

Abstract
Triaxial tests were conducted on two rock types using specimens ranging from 2 inches to 32 inches in diameter to determine the influence of specimen size on strength and mechanical properties. properties. While the influence of specimen size on mechanical properties was small, the effect on strength and character of failure was pronounced. Although sufficient data to verify statistical failure hypotheses was not collected, it is hoped that additional work now in progress will help in the development of more realistic models.

Introduction
Reduction of rock strength with increasing specimen size is a well known phenomenon which is of concern to those who deal with rock masses. Failure hypotheses have been advanced relating to both the statistical occurrence of macro-flaws (weakest link theory) and to the total available stored energy in the mass.
Most of the work to date in this connection has been conducted on confined specimens in the laboratory and related to measurements taken in the field. This has included empirical relationships based on the performance of mine pillars as well as the application of fracture mechanics. Triaxial tests have been performed mainly for the purpose of studying rock behavior under purpose of studying rock behavior under confining stress, and have been conducted with small specimens. No previous triaxial tests on the scale reported in this paper have been conducted to the best of the authors' knowledge. It is evident, therefore, that the current state of the art is qualitative rather than quantitative, and requires considerable effort in the future.
Electro-Chemical Purification of Hydraulic Pump Power Oils
Authors: Hettick Larry , Lucas Roy 
Published: December 2007

Abstract
The first commercial application of a new process for the purification of power oils has been in operation for a period of two years at production facilities operated by Long Beach Oil Development company. Evidence for the success of this installation is summarized in analytical data regarding the removal of water, particulate matter and water-soluble particulate matter and water-soluble salts from the make-up oil to the closed power oil system. of more interest is the sustained performance of the system itself - there has been a 50% decline in make-up oil requirement and a 70% reduction in engine repair costs since installation of the new process. process. Data from the precursory laboratory tests, the semi-works scale field prototype, and the commercial (1,500 B/D) prototype, and the commercial (1,500 B/D) installation are presented; of special interest is the information on the particle-size distributions of the particle-size distributions of the particulate matter in the oil. Detailed particulate matter in the oil. Detailed descriptions of the performance of the system, before and after the installation of the power oil treater, are included as are daily logs of the critical system parameters. Information comparing the parameters. Information comparing the performance of this new process with performance of this new process with those previously employed to remove impurities from power oils is also summarized.

Introduction
Erosion and wear of down-hole engine parts are often attributed to the presence of finely divided particulate matter present in the particulate matter present in the power fluid. Unfortunately, there power fluid. Unfortunately, there is relatively little information available regarding the nature of these solids or of correlations between their properties and engine maintenance. Although it seems desirable to remove the abrasive materials, there are few guide lines regarding design and performance of various systems which performance of various systems which could be used to clean these solids from power fluids or of the maintenance cost reductions which can be expected from such removal. The paper presented by Phelan before paper presented by Phelan before the 1953 Fall Meeting summarizes previously available information. previously available information.
Lithology and Fluid Properties and Their Relations to the Distribution of Saturating Fluids in Sandstones
Authors: Holmes M. , Dreher K.D. , Eloy A.J. 
Published: December 2007

Abstract
Cores from the Robinson sandstone, Crawford County, Illinois, were examined to investigate rock/saturation relations. Capillary pressure/ saturation data were obtained on the same suite of cores with fluids of different interfacial tensions using the centrifuge technique. The cores in every case were highly water-wet. Petrographic examination of core plugs as well Petrographic examination of core plugs as well as thin sections indicated that five basic pore groupings were present, on the basis of grain diameter and size and degree of interconnection of the visible pore structures.
Since deposition, the sandstone has undergone considerable pore modification by secondary post-depositional (diagenetic) processes. These have involved some pore processes. These have involved some pore enlargement but mainly porosity plugging accompanied by an increase in pore tortuosity. This history of secondary change can be seen in the way in which fluids saturate the rocks.
From the capillary pressure data, pore entry size distributions were determined, from which average pore entry size and a pseudo surface area term were calculated. Relations between these parameters vary with pore geometry. Evidence is presented which suggests that, at irreducible saturation, the wetting phase coats the rock surface as a uniform layer phase coats the rock surface as a uniform layer as well as blocking small pores. Data are presented which show that permeability is more presented which show that permeability is more closely related to pore entries at the large end of the distribution curve, rather than an average pore entry.

Introduction
Comparison of porosity (phi) with water saturation (Sw) has been used for many years to describe reservoir behavior. Archie indicated in a qualitative manner that net pay will depend upon how water saturation varies with porosity. He showed that the relationship between phi and irreducible water saturation (Swi) reflects the pore size classification. Following Archie's classification, mercury capillary pressure data were used, in conjunction with routine log analyses, to estimate oil-occupied pore space. Others have indicated that examination of phi versus Sw as a function of depth is of value to establish probable producing fluid and water mobility in probable producing fluid and water mobility in various zones of carbonate reservoirs.
In 1958, Weaver noted that phi x Swi is equal to a constant for homogeneous carbonates in which the matrix is essentially uniform.
Application Of The Wireline Formation Tester
Authors: Conrad K.M. 
Published: December 2007

Introduction
The Formation Tester, a wireline tool for safely and rapidly testing formations in the open hole, was introduced to the oil industry in 1955. Since its inception, it has proved to be a valuable evaluation tool. It provides a wireline method for obtaining an actual sample of formation fluids substantiated with formation pressure recordings.
Application of wireline testing has been extended to cased-hole testing, and improved in the open-hole testing of hard formations by the addition of the Formation Interval Tester. Thus, testers are currently available for use in almost any possibly productive zone — whether that zone be in open hole or behind casing/hard formation or soft.
Open-hole tests can be run in hole sizes of 6 to 12–1/4" in diameter under a hydrostatic pressure range of 500 to 20,000 psi. Cased-hole testing is available for casing sizes of 5–1/2 to 13–3/8" O.D. Fluid samples of 1, 2– 3/4 or 5–1/2 gallons may be recovered.
The purpose of this paper is to discuss the applications of these testers and the inter-pretation of their recoveries.