bluuebunny/crossref_metadata_2025_split huggingface dataset:
Enhanced Interpretation of Russian and Old Electrical Resistivity Logs Using Modeling and Inversion Methods
Authors: Frenkel M. A. , Mezzatesta A. G. , Strack K. -M. 
Published: December 2007

Abstract
The evaluation process for oil and gas reservoirs comprises the accurate estimation of underground formation resistivities. A substantial amount of Russian and old electrical log resistivity data has been acquired in the past that can be used in an enhanced interpretation process. Old electrical devices continue to be used in various parts of the world. Due to the characteristics of these instruments, which do not provide symmetric responses (unfocused logs), the data are difficult to interpret and require a large degree of expertise when conventional interpretation techniques are used (e.g., charttype processing). In addition, conventional interpretation does not allow for extracting all information contained in the data, for which oil and gas bearing formations may be overlooked.
Modeling and inversion methods represent an excellent way to interpret these types of resistivity logs. These methods allow for simultaneously interpreting the entire suite of available logs, incorporating the physics of the measurements, taking into account borehole, invasion, and shoulder-bed effects, and involving data uncertainties. Inversion methods provide reliable estimates of formation parameters and quality control indicators to assess the accuracy of the interpretation results.
A new philosophy for interpreting these resistivity logs, based on two-dimensional modeling and inversion, has been developed and a strategy implemented, allowing the log analyst to perform the full-spectrum of data processing required by the interpretation. The complete process involves the following major steps: data depth matching, mud resistivity estimation, log calibration, environmental corrections, utilization of prior information, and estimation of formation parameters.
The inversion technology has been implemented on both scalar and parallel machines, the latter providing a fast turn around time. The proposed scheme was evaluated on synthetic cases and applied to a set of Russian field data acquired in Western Siberia. The results are presented showing the proposed methodology's ability to obtain improved estimates of formation parameters and a consistent earth model explaining the entire suite of logs.
Tubing Joints For High Pressure Service
Authors: True Martin E. , O&apos;Reilly W.M. 
Published: December 2007

Abstract
Samples of tubing joints, considered as an item of well equipment very susceptible to leakage in high-pressure gas service, were subjected to a series of tests involving thermal changes and using gas at pressures to 15,000lb/sq.in. It appears that some joints commercially available and of special design give promise of adequately containing 15,000 lb/sq.in. gas pressure under field conditions. Observations indicate that physical turns as a measurement is superior to torque as an index of make-up and relative sealing ability of a joint.

Introduction
As wells are drilled deeper, reservoirs having pressures higher than those previously encountered impose greater requirements on production tubing strings. A 14,000-ft well was drilled recently in the Gulf Coast area which encountered a formation-bearing gas at a reservoir pressure of approximately12,100 lb/sq in. After completing the well it was deemed inadvisable to produce it because well control equipment tested hydrostatically to 15,000 lb/sq in did not adequately contain pressures encountered in this gas well. An investigation was initiated to devise a method of testing equipment for high pressure gas service and to locate equipment capable of retaining 15,000 lb/sq in gas pressure. Tubing joints are particularly susceptible to leakage because of the number used and because they cannot be fully and adequately tested in their installed condition. Experience has revealed that gas at high pressures will escape through porous metals of connections which appear adequate to contain liquids at equivalent pressures. One phase of the work of this investigation has been devoted to the determination of an adequate tubing joint. The purpose of this paper is (1) to present a method for gas testing of tubing joint connections rated for high-pressure gas service, and (2) to present an interpretation of observations obtained during testing of a number of these tubing joints.

Discussion
Previous testing of pipe connections filled with liquids at high pressure included subjecting specimens to beam loading, tension, pressure shocking, and extreme thermal changes. Subjecting tubing joint samples charged with gas at high pressures to thermal changes was believed to be a more demanding test of the joint, and an installation, shown in Fig. 1, was prepared to conduct such tests with relative safety. A metal box for use as an immersion bath was jacketed with a thick layer of protective sand and fitted with observation windows of shatter proof glass and an overhead sand box.
Interactive Simulation An Answer To What Is The Question
Authors: Kaplan Michel , Wentworth Robert C. , Bryson Larry D. 
Published: December 2007

Abstract
Simulation is an established technique that provides a rapid and effective means of provides a rapid and effective means of evaluating existing or proposed system operations. It has proved effective in assisting managers and designers to make decisions at significant cost reductions below real-life testing. This paper explores the research and problem definition aspects of simulation. It describes a new on-line simulation technique and emphasizes the merits of an interactive approach to modeling. This approach helps the user control, from a terminal, some decisions before all data are available and all alternative decision logic has been defined.
This approach is compared to standard simulation techniques throughout each step of development study. Examples are given from pipelines, fuel supply, and power supply systems, including tankers, barges, storage tanks, and power plants.

Introduction
In practice, it is management responsibility to make things work. Good management will make its decision on the basis of performance data and anticipated problems. performance data and anticipated problems. or react to difficulties as they are encountered. Management control is not necessarily automatic, and, therefore, its logic is not always easily programmed.
Essentially, management interacts with operations, according to planned decisions, and counteracts adverse conditions as they arise. Simulation is a tool that allows the manager to anticipate operational difficulties and pretest the consequences of his decisions on existing or proposed systems at significant cost reductions below real-life testing.
Quantitative Determination of the Degree of Heterogeneity Within an Outcropping Reservoir by Magnetic Resonance Imaging
Authors: Borgia G.C. , Bortolotti V. , Dattilo P. , Fantazzini P. 
Published: December 2007

Abstract
Under certain conditions, petrophysical analysis of outcropping rock units may add significantly to the knowledge of a buried reservoir by providing laterally continuous control of reservoir heterogeneity. We present here the first results of a project to develop cost saving methods to improve the knowledge of reservoir heterogeneity. The study was performed on a carbonate outcropping reservoir, and the sampled rocks can be correlated with oil bearing reservoir discovered some 50 km to the W, in the Southern Apennines. The cores are highly heterogeneous, with a consistent presence of fractures and vugs; therefore standard porosity measurements are difficult to perform. Quantitative Magnetic Resonance Imaging (MRI) was used to measure porosity. About 300 MRI internal images from 46 samples, taken from 8 full-size cores, were analyzed. Quantitative determination of porosity by MRI proved to be reliable to describe the distribution of porosity at different scales, and it was successful in providing information on the lateral continuity of the porosity.
P. 485
Statistical Study of Geopressured Reservoirs in Southwest Louisiana
Authors: Perry D.R. 
Published: December 2007

Abstract
This study is an investigation of the higher pressure gas reservoirs, often referred to as "geopressured" gas reservoirs due to the apparent support of the earth's overburden by the reservoir fluids. The geographical area investigated for geopressured reservoirs is limited to the onshore and offshore area of Southwestern Louisiana. Within this area, most of the gas producing reservoirs are Miocene age; however, older reservoirs (to Eocene age) are also found.
The contribution of this study is to call attention to the occurrence of geopressured reserves and the favorable economics of drilling developing and producing these reserves. The unexpected distribution of the larger percentage of economical reserves at the higher pressure gradients reverses the previous concepts that geopressured reservoirs would contain small volumes of reserves. This is of particular significance to the domestic industry which must continue to drill deeper to replenish its reserve storehouse.

Introduction
The correlation of the ratio or gradient of reservoir pressure to reservoir depth expressed at the geostatic ratio and the volume of recoverable reserves from above normally-pressured gas reservoirs is the objective of this study.
The geostatic ratios studied were above normal, meaning the reservoir pressure encountered exceeded the pressure exerted by a column of sea water at the depth the reservoir was penetrated. Reservoirs that contain penetrated. Reservoirs that contain higher-than-normal pressures are considered to be supporting a portion of the earth's overburden. They are often called "geopressured reservoirs," broadly meaning "earth pressured."
Geopressured reservoirs probably were first encountered by drilling wells over thirty years ago. Early well penetrations in these reservoirs could not be controlled and the wells were abandoned. The first such occurrences would likely have occurred along the Louisiana-Texas border of the Gulf of Mexico; however, geopressured reservoirs have been discovered in several foreign countries. Data from geopressured gas reservoirs located in South-western Louisiana (Figure 1) are used in this study.
Within the past twenty years the number of geopressured gas reservoirs developed has been large enough to make a valid investigation.
Shale Minerology and Overpressure: Some Case Histories of Pressure Detection Worldwide Utilizing Consistent Shale Minerology Parameters
Authors: Gill J.A. 
Published: December 2007

Abstract
While sands and permeable-carbonate reservoirs once served as a convenient source of pressure measurements—and of some erroneous concepts of pressure "graients" as well—we now realize that most fluid pressures originate in the relatively-impermeable clays and shales from whence they are transmitted to the sands and carbonates, where they tend to gradually bleed off and reach "hydrostatic" equilibrium.
The water being released dynamically, continuously, and currently from the younger shales (Tertiary and into Cretaceous), during their compaction and diagenesis, appears to be primarily responsible for the generation of overpressures. This shale-pressuring follows no consistently "linear" gradient, showing many irregularities and pressure "reversals"—thereby causing, and pressure "reversals"—thereby causing, and explaining, many of oar complex drilling problems. problems. Since shales—quite thick in comparison to the relatively thin sands-are the predominant "rock" in most of our predominant "rock" in most of our sedimentary basins, their water content becomes a tremendous hydrodynamic reservoir for fluid pressures, and perhaps the origin of the pressures, and perhaps the origin of the very hydrocarbons for which we are drilling The diagenetic changes in shale mineralogy which accompany the release and subsequent movement of internal water from shales are being utilized worldwide in a convenient and reliable group of parameters for monitoring pressure changes (either up or down) from shale cuttings while drilling is in progress. When these shale mineralogy parameters are properly interted (to allow for such things as "jump shifts" in geologic age caused by folding and faulting; missing sediments; or for 11 strange" minerals squirted spasmodically by volcanic activity into the depositing shale sediments), they tend to fit the preceding generalizations and verify dynamic preceding generalizations and verify dynamic considerations of overpressuring. Four such case histories are presented here.

Introduction
Dynamic mechanisms of pressure generation are not new to this group*, having been discussed in prior symposia by Jones, Burst and several others.
Deep Wells Bit Optimization
Authors: Hameed A. , Al-Rushaid A. 
Published: December 2007

Abstract
Case histories from Saudi Aramco fields are cited to demonstrate how enhanced rock strength calculations from open hole logs and core data, has aided Polycrystalline Diamond Compact (PDC) bit optimization. Cost per foot reduction was a challenging target to achieve with rotary, turbine or Positive Displacement Motor (PDM) in drilling deep, high temperature hard formations.

Introduction
With the increasing number of rigs deployed to drill deep gas production and exploration wells, Saudi Aramco has utilized state of the art PDC bits available in the market to minimize drilling costs.
It is well understood that the deeper we drill, the higher the temperature and rock compressive strength. This results in higher mud weight for most cases, slower rate of penetration and thus frequent bit trips that add to the well cost.
The use of PDC bits has greatly expanded over the last decade. The reason for this is that PDC bits generally drill faster, stay longer on bottom than a roller cone bit, and perform well for a wide range of difficult drilling conditions. Moreover, they are less likely to leave junk in the hole since they have no moving parts. Typically, PDC bits drill twice as fast as roller cone bits and can often replace two or three roller cone bits in places where they are successful, Since 1989, PDC bit life has increased 115% to an average of 3629 ft by mid 1995. The 13.7% annual increase in the average operational life of a PDC bit clearly explains the growing popularity of these tools.
It is a common knowledge that PDC yields the best results in soft to medium formations. Unlike roller cone bits, PDC cutting action is by shearing the rock not crushing. Therefore, less weight on bit is required to shear the rock. This shearing action leads to a higher rate of penetrations in rocks like shales and limestone. PDC bits can be destroyed in hard formations such as granite or quartz or by nodular formations such as chert or pyrite.
The objective is to drill a well with a minimum feasible cost at the highest standards of safety and well integrity. This can be achieved by increasing the rate of penetration (ROP) and reduce the cost per foot (CPF) by using PDC bits on rotary, PDM motor and turbine.
This paper will present case histories from Saudi Aramco fields and illustrate how open hole logs, mud logs, offset bit records along with core data were utilized in analyzing the rock compressive strength and internal angle of friction to predict the drillability of the formation in order to optimize bit selection.
Collision Avoidance Using a Single Wire Magnetic Ranging Technique at Milne Point, Alaska
Authors: Mallary C.R. , Williamson H.S. , Pitzer R. , Robertson James 
Published: December 2007

Abstract
In high well density environments, wellbore collision avoidance typically requires creative trajectory planning, carefully executed directional drilling and rigorous downhole surveying. In exceptionally congested developments, these techniques alone may prove inadequate for accessing certain targets without violating close-approach policies. In Alaska, an adaptation of magnetic ranging technology originally developed for relief well drilling provides a safe, cost-effective alternative for drilling through such congestion. This magnetic ranging technique has been used to successfully drill to an otherwise inaccessible target.
P. 813
Geotechnical Investigations for Arctic Gas Pipelines
Authors: Bruce William 
Published: December 2007

Abstract.
The sub-surface conditions encountered in the Arctic, critical to a natural gas pipeline design, construction and operation, require a comprehensive investigation and analysis of these conditions before confidence can exist that ground stability can be preserved. The paper outlines the preserved. The paper outlines the geotechnical investigations, analysis and design consideration performed by the Canadian Arctic Gas Study group in evaluating a gas pipeline to the Arctic.
Programs covering photo-interpretation, soils investigations, geology, mathematical modelling are explained.
The thrust of most Arcticpipeline studies is toward the delineation pipeline studies is toward the delineation and solution of problems related to permafrost. Prior to the Prudhoe Bay permafrost. Prior to the Prudhoe Bay discovery, permafrost research was viewed by many as a scientific luxury and little was known of its characteristics and behaviour. Although permafrost covers one-half of the land area permafrost covers one-half of the land area of Alaska and Canada, the engineering fraternity had demonstrated only a nominal interest into this phenomenon. The value of such information was suspect, and the hostilities of the Arctic environment was generally conceded as the major deterrent to development. our lack of knowledge of permafrost became painfully clear in 1968 and was dramatized by our urgent need for it.
The problem was magnified by the public concern and pressures for public concern and pressures for environmental preservation. No longer can the designer be satisfied with are liable and economic design, he must demonstrate that environmental disturbance is maintained with inacceptable limits. The Arctic and sub-Arctic present the supreme challenge in doing present the supreme challenge in doing so.
Most of the design and environmental concerns are related, directly or indirectly, to geotechnical problems arising from thermal changes to the permafrost, from any number of sources. permafrost, from any number of sources. Extensive knowledge has been gained in this field and analytical techniques developed to confront most foreseeable problems. problems.

The Canadian Arctic Gas Study Limited
This consortium developed from the 1972 merger and subsequent expansion of two formerly competitive groups formed to study a natural gas pipeline connection to Prudhoe Bay. By July of 1972, sponsoring companies numbered sixteen and represented production, transmission, and transportation interests.
New Results on the Displacement of a Fluid By Another in a Porous Medium
Authors: Delclaud J.P. 
Published: December 2007

Abstract
Reservoir engineers have many problems in forecasting the oilfields exploitation if they use the laboratory data on the relative permeability curve vs saturation. permeability curve vs saturation. This leads one to wonder whether this concept is valid in transient flow, whether data have been made by suitable methods, whether the static relation between capillary pressure vs saturation is preserved in variable flow, whether lack of familiarity with combination laws concerning this function is not the reason for the dissatisfaction of the engineers. The present paper deals with the first three points. present paper deals with the first three points. Three series of oil displacement by gas have been made on a homogeneous sandstone core. Pressure in the two phases and saturation Pressure in the two phases and saturation (gammagraphy) have been measured all along the core. Pressure profiles have been found by the least-square method. Relative permeability has been calculated on each point and at each time by continuous equations.
These studies have shown us that the relation relative permeability vs saturation is the same all along the transient fluid flow and that the relation capillary pressure vs saturation is the same as the one established by the restored states static method. Thus, the validity of this concept concerning transient fluid flow is proved. The Welge, Johnson, Bossler and Naumann method arrives at different results from those we have obtained. To explain this difference we show that the theoretical hypotheses of their method are far removed from reality.
In conclusion, experimental results are simulated by numerical model taking into account capillary phenomena. The limit conditions established by experiments and used in numerical simulation are (1) inflow side (constant gas-injection pressure; pressure gradient is zero in oil) and (2) outflow side (out-gas pressure equal to the displacement pressure; pressure in oil is zero). The pressures are relative pressures. pressures

Introduction
When sweep efficiency of one fluid displacing another has to be predicted, the approach to the problem is nearly always identical. Laboratory displacement tests are performed on small samples that are supposed to performed on small samples that are supposed to be representative of the reservoir. After analyzing the data by the simplified method of Welge, Johnson, Bossler and Neumann, the relative permeability-saturation relationships are derived. In order to characterize more completely the porous medium, the capillary pressure-saturation relationship is also pressure-saturation relationship is also determined by the restored-state technique.