bluuebunny/crossref_metadata_2025_split huggingface dataset:
Development of Slickline Logging Tools for Very High-Temperature Applications
Authors: Carson C. C. , Wolfenbarger F. M. 
Published: December 2007

ABSTRACT
Five logging tools were developed for collecting data in the DOE-sponsored Salton Sea Scientific Drilling Project (SSSDP) well. The tools were designed to function at temperatures up to 400°C (752°F) and were successfully operated in the well at temperatures of 360°C (680°F). All of the tools—mechanical units for measuring and recording temperature, pressure, and flow rate; an electronic memory tool for measuring and recording temperature and pressure; and a special purpose battery pack for powering a downhole fluid sampler—are designed for slickline operation. In each, selected critical components are placed inside a dewar that provides thermal protection for a limited time. This paper discusses the tools, their development and operation, the results from their use in the SSSDP well, and potential extensions to geothermal and gas well applications.
Pulse Testing Reveals Poor Lateral and Vertical Continuity in a Reservoir Consisting of Distributary-Channel Sands
Authors: Roest J. A. , Jolly D. C. , Rodriguez R. A. 
Published: December 2007

Abstract
Pulse testing revealed that free gas had accumulated against an unexpected permeability barrier in a watered-out sandstone reservoir. It also suggested vertical permeabilities to be poor. This interpretation, which was confirmed by production tests and build-up surveys, led to a refinement of the geological reservoir model.
Furthermore, valuable insight was obtained into the interpretation of pulse tests in areally heterogeneous reservoirs.
Sata Log
Authors: Thurber C.H. , Gay B.J. 
Published: December 2007

Abstract
A new logging technique known as the Sata log is now being routinely run which exhibits two curves of the acoustic family. One curve is the transmission amplitude of the received signal, the other curve is the attenuation of the acoustic signal as shown by the difference in amplitude between two receivers. The log has shown that gas, oil and water may be distinguished on a qualitative basis in both high-and low-porosity media. The basis principles of the two curves are discussed which covers the consideration of the coefficient of coupling of the fluid to the formation and, also, the coefficient of coupling with respect to formation to formation in a vertical sense and the relative relationship of the transmission of the acoustic signal within the formation as an independent entity bearing little influence from the mud to formation effect. Examples of logs are shown which illustrate the effects of fresh-water sands on other logs, as compared to its effect on the Sata log. Wet or dry sands are illustrated, and comparisons of gas and wet formations are illustrated.
No quantitative claims for this logging technique are being made. The Sata log also has the unique ability to log in casing, showing conditions behind the casing which lead to the location of cement tops. Formations may be logged through the casing when the formations are in contact with the casing.

Introduction
A new type of log called the Sata log, which appears to give direct indications of water, oil and gas content of porous media in a borehole, is being made available to the oil industry.
The name "Sata" comes from the identifying letters applied to the two curves represented by this logging technique. SA is the abbreviation for signal attenuation; TA is the abbreviation for transmission amplitude. These two curves are part of the family of acoustic parameters - velocity, wave length, frequency, amplitude, attenuation, acoustic impedance and others.

Theory
The Sata log differs from acoustic velocity logging by logging the amplitude and attenuation of the signal rather than the travel time. Signal character has been described in literature previously.
Fig. 1 shows an idealized-received logging signal as seen on the monitoring scope. The horizontal sweep is in time and the vertical displacement is in amplitude. Only the first peak of the negatively going signal is measured since this cycle is probably the result of the bulk modulus wave. Isolation of the measurement of this cycle is made to prevent the questionable influence of the water, shear, tube and reflected waves which follow.
Two-Phase Flow through Chokes
Authors: Sachdeva R. , Schmidt Z. , Brill J. P. , Blais R. M. 
Published: December 2007

ABSTRACT
Two-phase flow through wellhead chokes, including both critical and subcritical flow and the boundary between them, was studied. Data were gathered for air-water and air-kerosene flows through five choke diameters from 1/4 in. (6.35 mm) to 1/2 in. (12.7 mm), and results were compared to published correlations. A new theoretical model for predicting flow rates and the critical-subcritical flow boundary was tested against these data, as well as data from two published studies. The new model substantially improves the existing methods for predicting choke behavior in two-phase flow.
The Analysis of Amplitude vs. Offset To Detect Hydrocarbon Contacts in Saudi Arabia
Authors: Chiburis E. F. 
Published: December 2007

ABSTRACT
Analyses of seismic amplitude vs offset (source to receiver distance), AVO, can yield information regarding the physical properties of the reflecting horizons. Specifically, changes in formation fluid content are theoretically discernible in the behavioral changes in AVO, due principally to changes in the Poisson's ratio of the rock units. An AVO analysis of five seismic lines across an oil field in Saudi Arabia was conducted in an attempt to detect the spatial position of the oil/water contacts. The results indicate that the AVO patterns are directly correlative with the known fluid contacts in the area.
Offshore Storm Design Criteria Improvements by Hindcasting and Joint-Probability Analysis of Results in the Arabian Gulf
Authors: Shabib H. M. 
Published: December 2007

Abstract
This paper describes the methodology and results of a hindcasting study used to predict offshore storm design criteria in the Arabian Gulf for 1,10 and 100 year return periods. The paper further describes the benefit of applying joint probability concept to the hindcast results in estimating design forces. The result for the structure described herein is a reduction of the 100 year design force by 31 percent.
A recent storm hindcast study in the Arabian Gulf involved a review of the offshore storm design criteria and an extreme event analysis for major Saudi Arabian fields. The results of the study were a set of design criteria for winds, waves, currents and surge levels for return periods of 1, 10, and 100 years.
The outcome of the study was a significant improvement on the design parameters previously used. Conservatism was reduced by the use of state-of-the-art numerical hindcast models that had been validated with measured data. The study considered directionality of wind and currents and accounted for refraction of waves in the shallow fields.
Viscosity Correlations for Saudi Arabian Crude Oils
Authors: Khan S. A. , Al-Marhoun M. A. , Duffuaa S. O. , Abu-Khamsin S. A. 
Published: December 2007

ABSTRACT
Empirical equations for estimating viscosity: above, at, and below the bubble point pressure were developed based on data from Saudi Arabian crude oils. Both statistical and graphical techniques have been employed to evaluate these equations as compared to other published crude oil viscosity correlations using the same data. It is shown that the developed correlations provide more accurate estimates of viscosity in all three regimes of pressure.
An Overview of Gas Production, Distribution, and Conservation Policies in the Sultanate of Oman
Authors: Al-Hinai K. B. M. , Al-Balushi S. B. S. , Madhava N. 
Published: December 2007

ABSTRACT
Natural gas is assuming greater importance in Oman with increasing demands for power generation, oil field usage and other industrial uses. The steps being taken by the Ministry of Petroleum arid Minerals are described within, which comprise of exploration and evaluation programs; construction of a gas distributionnet work and expansion plans; gas conservation and utilization operations.
This paper describes the various phases involved and the associated milti-disciplinary interactions/coordination that is required to anticipate and ensure proper action. Based on long term gas demand some of the efforts that are being made to generate adequate gas resources are outlined.
Notwithstanding the uncertainties associated 1 with the projected gas demands and the international market prices for natural gas the paper assesses the current problems and prospects.
Energy Conservation in Oil Fields
Authors: Ansari M. A. , Eissa A. M. 
Published: December 2007

ABSTRACT
Kuwait Oil Company confronted with shortage of gas at low oil production rates in 1983 conducted an energy audit in oil fields in South East Kuwait. Production history of 1981-82 was studied for production rates, GORs, selection of gathering centres and operational practices. Testing of production facilities followed to record process parameters, fluid analysis, energy consumption, machinery performance and gas losses. Computer simulation models were developed to generate case studies at optimum conditions. Economies in energy through changes in operational modes and equipment modification were evaluated at US $ 4.18 million/year minimum to 21.62 million/year maximum with 3.75 years payout period.
The Effect of Overburden Pressure on Relative Permeability
Authors: Ali H. S. , Al-Marhoun M. A. , Abu-Khamsin S. A. , Celik M. S. 
Published: December 2007

ABSTRACT
In routine core analysis, porosity and permeability, both relative and absolute, are measured on rock samples which are not under net overburden (confining) pressure. Using these data to predict reservoir performance or estimate reserves can lead to serious errors since all reservoirs are under net overburden pressure.
Data collected from constant rate, dynamic displacement experiments were utilized to study the effect of net overburden pressure on porosity and absolute and relative permeabilities. These experiments were conducted on small, consolidated rock samples under net overburden pressures up to 41.37 MPa (6000 psi) and room temperature. The pore pressure was maintained atmospheric.
Examination of the data shows a decrease in porosity and permeability with increase in overburden pressure. A correlation between porosity and overburden pressure and also between permeability and overburden pressure has been developed using linear regression analysis. Both correlations are found to be logarithmic. The irreducible water saturation and residual oil saturation increase with increased overburden pressure levels. While the relative permeability to oil decreases with increasing overburden pressure, a corresponding negligible decrease in water relative permeability is observed.
An Improved Technique for Estimating Permeability in Carbonates
Authors: Watfa M. , Youssef F. Z. 
Published: December 2007

ABSTRACT
The permeability of a reservoir is a function of fluid type, pore size and distribution, facies type, sha-liness and heterogeneities such as non-connecting vugs and fractures. Many equations and statistical techniques have been proposed to predict permeabilities using logs or log-derived results such as porosity and irreducible water saturation. However, none of the proposed techniques can be used universally since a particular relationship in one field or for a particular facies cannot be extended to other fields or facies. The standard procedure at present is to experiment with functions on a trial and error basis to establish correlations between core-derived permeabilities and log measurements. In carbonate formations, where structural heterogeneities and textural changes are common, the applications of these techniques are very limited.
A new technique has been developed to improve permeability estimates in carbonates. The technique aims to quantify both the field-wide variations and local variations in a reservoir. A theoretical model has been developed which defines the permeability of a porous medium as flow path length and pore radius change. The effects of heterogeneities, such as vugs and fractures, are also considered in the modelling. Correlations are established between the important geometrical factors that were determined in the model, and log-derived results such as the Archie factor m, the total porosity and the secondary porosity. The paper discusses in detail the principle and mathematical deriviations of this model and presents examples which demonstrate the improved accuracy of the permeability estimates as compared with proposed techniques for estimating permeability.
An Overview of the Formation Evaluation of Recent Discoveries in the Thamama, Arab, and Araej Reservoirs, Offshore Abu Dhabi
Authors: Azer S. R. , Borai A. M. 
Published: December 2007

ABSTRACT
The Lower Cretaceous Thamama group, the Upper Jurassic Arab Formation and the Middle Jurassic Araej Formation are potential reservoirs and carry the bulk of the hydrocarbons-in-place in offshore Abu Dhabi.
Testing of these reservoirs in some areas revealed that drastic discrepancies existed when comparing test results with computer processed interpretations (CPIs) for well logs.
Reservoirs which tested water free hydrocarbons were indicated to be water bearing on well logs.
Several anomalous examples from the above mentioned reservoirs were studied.
The integration of all pertinent data is of utmost importance for proper formation evaluation.
The geological factors of different formations, which affect log measurements are the products of depositional and diagenetic processes.
Petrophysically, the cementation factor, thin bedding and deep invasion are critical when computing water saturation. A new log interpretation model is developed to decipher this formation evaluation problem, which resulted in more realistic water saturation calculations.
Diagenetic Effects on Reservoir Properties of the Permian Khuff Formation in Eastern Saudi Arabia
Authors: Al-Jallal I. A. 
Published: December 2007

ABSTRACT
The Permian Khuff Formation represents the earliest major transgressive carbonates deposited on a shallow continental shelf in eastern Saudi Arabia. A detailed study was made of slabbed cores and thin sections from various wells recently drilled into this rock unit. The Khuff Formation was deposited in tidal flat environments including subtidal, intertidal and sabkha (supratidal). These depositional environments represent four major cycles. Each cycle starts with a transgressive grainstone facies which makes up the Khuff reservoirs and ends with regressive, muddy and anhydritic facies which make up the non-reservoir units.
Development of reservoir quality appears to be complexly controlled by lateral continuity or discontinuity of depositional facies and, more effectively, by diagenesis. Because of these lateral changes, Khuff reservoir development does not exactly follow present structural position. Some wells located on present structural highs are in non-reservoir facies, while other structurally lower wells are very porous.
Diagenesis has both increased and/or decreased reservoir quality. In places, dolomitization and leaching have enhanced the reservoir porosity and permeability. In other places, dolomitization and/ or cementation have seriously decreased the porosity and permeability.
Good porosity and permeability are related to the preservation of primary interparticle pores in totally dolomitized grainstones or leaching of remaining calcite in dolomitized mudstones. The later process produces secondary intercrystalline pores. Good porosity and poor permeability probably reflect an early exposure to fresh water leaching in grainstones, producing unconnected or poorly connected moldic pores. Poor porosity and permeability are caused by one or more of the diagenetic effects of cementation, dolomitization, or absence of leaching in all facies types.
Current studies show that Khuff reservoir changes can be described by a combination of depositional and diagenetic models. However, prediction of reservoir continuity is possible only for short distances from existing wells.
Camurlu Field Immiscibie CO2 Huff and Puff Pilot Project
Authors: Gondiken S. 
Published: December 2007

ABSTRACT
A pilot project of enhanced oil recovery by CO2 injection has been carried out in Camurlu field for the first time in Turkey. CO2 gas was injected without using a compressor into selected C-11 and C-22 wells for three consequtive cycles during two years. Five or six fold increases in daily oil production rates of the wells especially within the first few weeks of last cycles have been observed. Field-wide application was decided since it has been understood that better working conditions and better selection of equipment and materials could yield much better results.
Design Factors and their Influence on Profile Modification Treatments for Waterfloods
Authors: Avery M. R. , Gruenenfelder M. A. , Tarlton J. M. 
Published: December 2007

ABSTRACT
In the past 5 years, chemical profile modification for water injection wells has evolved from the experimental stage to a routine procedure. Chemical profile modification can be used under a wide range of reservoir conditions to treat a variety of reservoir heterogeneities known as thief zones. This paper presents a discussion of the typical thief zone problems, how they are diagnosed and the design process necessary for a successful profile modification treatment.
Case Study: Enhanced Oil Recovery Potential for the Garzan Field, Turkey
Authors: Warren G. M. , Memioglu E. , Bakiler C. S. 
Published: December 2007

ABSTRACT
The Garzan B and C Pools, located in southeast-central Turkey (Figure 1), were studied for enhanced oil recovery (EOR) potential. A review of this study is presented in this paper.
The study consisted of a review of geological and reservoir engineering data followed by black oil reservoir simulation history matching of primary and waterflood depletion phases over a 27 year period. Selected pattern elements were then subjected to various EOR processes using compositional and thermal simulation models. The optimal EOR process, selected on the basis of technical and economic criteria, was extrapolated to full field scale and compared to optimized waterflood simulation predictions.
The study predicts that immiscible Dodan gas (mainly CO2) injection on 54 acre [21.9 ha] inverted 9-spot patterns will provide enough recovery and economic benefits over optimized waterflooding to warrant proceeding with a pilot gas injection scheme.
Case History of an Immiscible Gas Injection Pilot in a Massive Carbonate Reservoir with Water Drive
Authors: Welch V. S. 
Published: December 2007

ABSTRACT
This paper describes a case history of an immiscible gas injection pilot which was carried out in a massive, carbonate reservoir in the Middle East. The reservoir contains an undersaturated, intermediate gravity oil, and recovery was less than five percent after 40 years natural depletion by intermediate to strong edge-water drive. Immiscible gas injection was recognized as a potentially economic recovery process and a gas injection pilot was initiated in 1983. A cross-sectional model study has provided the basis for evaluating and confirming the success of the gas injection pilot. A numerical simulator was used to match the 40 years of natural depletion followed by two years of immiscible gas injection. Performance was then predicted for two future operating plans. Reservoir analysis data collected during the injection shut-in and during an additional six months of gas injection, following the shut-in period, show that the reservoir mechanisms predicted by simulation to improve performance and recovery are operative. This paper discusses the description of the reservoir and its history, the model description and application, history match and 20-year predictions, and one year post-operative performance following the history match period.
Exploitation of Sui Main Limestone Reservoir at Sui: The Prolific Gas Producer of Pakistan
Authors: Schail H. M. , Sadiq F. 
Published: December 2007

ABSTRACT
Sui Main Limestone (SML) is the most prolific reservoir accounting for 90% of all production from Sui Gas Field. Work carried out for obtaining estimates of reserves, future production potential and ultimate recovery from the SML reservoir is discussed. The paper presents results of well coning and reservoir simulation studies conducted. Work carried out in determining the reservoir's future compression requirements (over 75,000 HP) and debottlenecking of wells and gas gathering system is also highlighted.
The paper highlights the monitoring/ control of production operations for SML. Casing/tubing corrosion, failure and resulting fluid seepages are discussed. Problems related to formation water production and its monitoring/removal are presented.
The Fracmeter: A New Numerical Method to Evaluate the State of Stress and the Elastic Properties of Rocks
Authors: Charlez P. , Saleh K. , Despax D. 
Published: December 2007

ABSTRACT
The fracmeter is a straddle inflatable packer with a spacing fitted with radial displacement transducers. When a hydraulic fracture is created it can be shown that the displacement field around the wellbore becomes anisotropic with a maximum value perpendicular to the fracture plane.
The multiplication of the number of equations relating the radial displacement of the borehole and the pressure makes it possible by an appropriate inverse method to determine with a single test the two horizontal geostatic stresses, the elastic constants of the rock and the fracture azimuth.
Gas Injection in the Eastern Fault Block of the Thistle Field
Authors: Laidlaw W. , Bayat M. G. , Tehrani A. D. H. 
Published: December 2007

ABSTRACT
Gas injection commenced in the Thistle field early in 1980, to conserve excess produced gas. By April 1984, 4.3 billion scf [122 × 106 m3] of gas had been injected in a single down-flank well. Analysis of the reservoir performance indicates that about 543 Mstb [86 × 103 m3] of additional oil was produced as a direct result of the gas injected. The net gas used, allowing for produced injected gas and additional fuel gas for compression was 3.2 bscf [90 × 106 m3], resulting in a gas-to-recovered-oil ratio of 5.8 Mscf/stb [1040 m3/m3].