bluuebunny/crossref_metadata_2025_split huggingface dataset:
First Monitoring Well in the Rabi Field: Design and Data Gathering
Authors: Alixant J-L. , Storey Martin 
Published: December 2007

ABSTRACT
To optimise the Rabi Phase II field development plan, uncertainties on key petrophysical parameters had to be reduced below those normally achieved using conventional techniques. Core analysis results were not satisfactory because the reservoir sandstones are unconsolidated. It was decided to determine the petrophysical parameters in-situ, measuring certain reservoir properties using several independent techniques. A dedicated well was drilled specifically for this purpose.
This paper explains why it became necessary to drill the data gathering and monitoring well, and how the well was designed to ensure it would yield representative data. Important objectives were to improve the quality of base-logs, and to reduce environmental effects on time-lapse measurements. Key features of the well are described, including: A glass-reinforced Plexiglas (GRP) window, for time-lapse resistivity logging;Latch points over the reservoir section, for precise and repeatable depth-positioning of the Borehole Gravity Meter.
The comprehensive data acquisition programme is discussed, and open-hole logs are compared to initial cased-hole logs recorded in the GRP section.
A Transient Wellbore/Reservoir Model for Testing Gas Wells in High-Temperature Reservoirs, Part II. Field Application
Authors: Kabir C. S. , Hasan A. R. , Jordan D. L. , Wang X. 
Published: December 2007

Abstract
This paper describes the application of the transient wellbore/reservoir model developed in Part I of this work. The model allows forward simulation of wellhead pressure and temperature and bottomhole pressure as a function of time, given reservoir parameters and well completion details. Another simulator has been developed that directly translates measured wellhead pressure (WHP) and temperature (WHT) to bottomhole pressure (BHP) for subsequent analysis.
Forward simulation of wellbore pressure and temperature is a valuable tool for designing transient well tests. In particular, in a hostile downhole environment, the ability to estimate BHP accurately from wellhead measurements is an invaluable asset where downhole measurements may not be cost effective. Even in favorable situations, the simulator can aid both test design and interpretation.
Application of the simulator to field examples has helped us gain considerable insight into the mechanics of transient flow in the wellbore. For example, we observe a denser fluid towards the wellhead rather than at the bottom of the well because of the temperature effect. Consequently, decreasing storage behavior is observed at the bottom of the well.
Two field examples, obtained from a Gulf Coast gas field, are used to illustrate the capabilities of the simulators. Good agreement is noted between the computed and measured BHPs during both types of simulations.
New Cumulative Rate Convolution Analysis for Closed Chamber Test
Authors: Zhan Lang , Liu Weining , Chen Qinlei 
Published: December 2007

AbstractClosed Chamber Test has aroused much interest recently for its short test time, simple operation and sound safety. However, variable wellbore conditions and rapidly changing sandface rate make interpretation difficult. In this work, the conception of effective wellbore storage coefficient proposed by Xiao and Reynolds1 is extended to obtain analytical functions of chamber gas pressure, effective wellbore storage and cumulative rate for a CCT. The influence of varying tool and reservoir parameters is discussed by using these functions. A simple numerical method is used to estimate cumulative rate by chamber gas pressure when friction and real gas behavior effects are important. As a principal contribution of this work, a Cumulative Rate Convolution technique is introduced for a CCT. It is shown that uncertainty coming from pressure differential to obtain sandface flow rate can be avoided by CRC technique. Skin factor S is directly determined in CRC plot, and initial reservoir pressure also can be estimated by extrapolating time function group to zero. It is shown that superposition model for shut-in data1 can be used in CRC technique, thus integrate interpretation including flow period and subsequent buildup transient data can be performed to enhance analysis confidence
Through Casing Formation Density Measurements
Authors: Wolcott D. S. , Vittachi Amal 
Published: December 2007

Abstract
Due to the high drilling costs associated with operating in a remote environment, there are strong incentives for reducing operating costs to maintain the economic viability of the field. One aspect of cost curtailment is reducing well evaluation costs. A solution is to utilize cased hole measurements which offer cost savings and reduced risk.
Using a specially modified wireline density tool, reliable measurements of formation bulk density can be obtained through casing. This measurement costs less than a measurement while drilling (MWD) density tool and reduces the chance of lost tool charges.
The cased hole density tool was constructed with source and receivers spaced further apart than on traditional open hole density tools allowing a deeper depth of investigation. A density correction algorithm has been developed to remove the effects of casing and cement to obtain a true formation density measurement. The tool has been run in over 15 wells, and comparisons with MWD and open hole wireline density data demonstrate the measurement is accurate and reliable.
The availability of a cased hole density tool has allowed greater flexibility in the design of logging programs. In horizontal and extended reach wells, the use of MWD density tools, which require full gauge stabilizers, can hinder steering. Also, MWD formation evaluation (FE) tools are limited to 8.5 in. or larger boreholes. By eliminating the MWD density-neutron tool in the open hole string, and making the measurement with the cased hole density, considerable operational and cost benefits can be realized. Because of lower cost and reduced risk the cased hole density tool offers a reliable and safe alternative to open hole density measurements.
Early Quantification of Hydrocarbon in Place Through Geostatistical Object Modelling and Connectivity Computations
Authors: Petit F. M. , Biver P. Y. , Calatayud P. M. , Lesueur J-L. , Alabert F. G. 
Published: December 2007

ABSTRACT
A methodology of HIP quantification using geostatistical object simulations and connectivity calculations is proposed and tested on a gas field in appraisal phase.The object-modelling algorithm allows for a realistic representation of the shapes of sedimentary bodies and hence a fair modelling of reservoir heterogeneities and of their connections. As a classical volumetric computation is not appropriate due to a complex repartition of fluids and the presence of two types of gas, a static connectivity algorithm is used to quantify volumes which are connected to assumed gas-feeding sources; HIP values are deduced from this technique.
As major uncertainties exist on geological parameters, four scenarios are defined thanks to bootstrap calculations on well data; for each scenario, several geostatistical realizations are generated. Resulting figures provide the total uncertainty on GIP.
The sensitivity of results to the percolation cut-off is also estimated. The connectivity algorithm is questioned in terms of sensitivity to the grid block size.
Influence Functions for the Analysis of Well Test Data From Heterogeneous Permeability Distributions
Authors: Tauzin Eric , Horne R. N. 
Published: December 2007

Abstract
The simulated annealing solution technique has been a powerful reservoir characterization tool in geostatistics. This paper proposes an algorithm that uses this method to constrain the permeability distribution of a given reservoir model to the well test data collected at several wells. The technique can be used for single or multiple well tests.
In order to keep the execution time of this algorithm within an acceptable range, the perturbation on the pressure transient due to a local permeability heterogeneity is determined in the form of an analytic influence function. The results given by this approximation are compared to the results given by a simulator, and its use in the simulated annealing algorithm is defined according to its reliability. The algorithm is tested on an example, showing that the use of the analytic influence function allows considerable reduction in the computing time without decreasing the robustness of the method.
Porosity and Reservoir Thickness From Core, Log, and Seismic Measurements
Authors: Marion D. P. , Jizba D. L. , Vernassa Sylviane 
Published: December 2007

ABSTRACT
We present a method that uses combined information acquired at core, log and seismic scale for improved reservoir delineation and characterisation. In the paper, we illustrate how the method is applied to estimate porosity and reservoir thickness on a carbonate oil field. This work shows that once proper calibration is performed using core and log measurements, seismic measurements can be used to quantify lateral variations of rock properties and hence constrain reservoir simulation models.
Integrating Well Log Data, Drilling Data, and Laboratory Data for the Determination of Maximum Drawdown Limits in the Presence of Weak Sands
Authors: Pennington W. D. , Edwards D. P. 
Published: December 2007

Abstract
The ability to predict sand failure in producing wells is important for the economic planning of the development and management of oil and gas reservoirs. Anticipated failure of weak sands often limits the production rates from wells, perhaps unnecessarily in many cases. Sand failure can occur either as a transient phenomenon, as perforation tunnels enlarge in response to shear failure in the vicinity of the borehole, or it can occur continuously, as intact rock crumbles and is produced into the wellbore. These failure conditions can be predicted from wireline logs, estimates of in-situ stress, and laboratory tests of strength on core plugs. The strength tests on core plugs can often be divided into two classes: those that indicate that the rock contained a plane of weakness, on which failure occurred easily; and those that indicate the rock was essentially intact. The strength of the weaker class of rocks is indicative of the "rock mass strength," including flaws and planes of weakness; residual strength tests conducted on these samples can be used to predict a reduced state of stress after initial failure. The strength of the stronger class of rocks is indicative of the "intact rock strength" and is used to predict the potentially catastrophic conditions of continuous sand production, when compared with the reduced state of stress after initial failure. The recognition of the two classes of core plugs together with the assumption of a predictable reduced state of stress leads to more optimistic drawdown scenarios than would otherwise be determined.
This model has been applied to a number of fields, including one from the Gulf of Mexico which was discovered very near an older field known to contain extremely weak and unconsolidated sands. After a thorough analysis, it was concluded that the newer field was in fact quite strong, and production rates were increased considerably beyond those that had been considered to be safe prior to the study.
Gas-Lift Optimization in a Large, Mature GOM Field
Authors: Everitt T. A. 
Published: December 2007

Abstract
This paper describes the processes and results of an extensive gas-lift optimization effort executed at the field level in South Pass Block 24 (SP24) of the Gulf of Mexico. The processes described herein include data gathering, problem identification, and problem resolutions which resulted in a 50% reduction in lift gas requirements.
An Updated Data Gathering System To Optimize Production Operations
Authors: Patterson J. C. , Curfew J. V. , Bucaram S. M. 
Published: December 2007

Abstract
Failure control is a critical path to optimizing operations in today’s petroleum industry. Failure control in its simplest form is failure analysis with the goal of achieving corrective action. Accurate records and meaningful reports are a key part of any failure control program. This paper is the third in a series involving the data gathering and processing system used by Atlantic Richfield to optimize production operations and discusses the new PC system version. Application is demonstrated by identifying some rod pumping problems, suggested solutions, and results.
An Innovative Cell To Control the Gas-Tightness of Cement Slurries
Authors: Degouy D. G. , Large P. R. 
Published: December 2007

Abstract
This paper presents an innovative gas migration test cell, fully automated, developed to evaluate cement slurries for gas well cementing. A low pressure regime, consistent with the actual hydrostatic pressure exerted by the cement column, is applied in the cell. The gas migration process is therefore only governed by the evolution of the intrinsic characteristics of the slurry. A comparative study on several commercially available additives and a parametric study on one of these additives have been undertaken. Results obtained are presented and discussed.
Downhole Performance Evaluation of Blast Furnace Slag-Based Cements: Onshore and Offshore Field Applications
Authors: Leimkuhler J. M. , Rambow F. H. K. , Warren P. B. , Javanmardi K. , Ladner B. S. , Smith T. R. 
Published: December 2007

Abstract
Shell has used BFS cements on over 160 oil well cementing operations as part of an effort to develop and expand the understanding of blast furnace slag (BFS)-based cements. Well types include major deepwater development wells to sidetracks drilled with a workover rig. Downhole conditions range from cold deepwater applications to shallow thermal wells subjected to cyclic steam injection.
To date, the field performance of slag-based cement has met or exceeded expectations. Formation integrity tests, bond logs, and production data indicate good annular isolation. Casing shoe integrity test datafrom exploratory and development wells show a lower incidence of remedial squeezing prior to drilling ahead as compared to Portland cements. Contrary to previously reported bond-log evaluations, conducted under laboratory conditions, downhole bond logs under saturated conditions indicate an improved casing/cement bond with time. Production data from wells with dual completions indicate good zonal isolation between perforated intervals. Leak-off test data for slag-based cement jobs conducted in the Gulf of Mexico are reported for each casing size. Field data for squeeze cementing casing shoes, liner tops, and casing annuli are also presented.
Hydrate Formation/Inhibition During Deepwater Subsea Completion Operations
Authors: Peavy M. A. , Cayias J. L. 
Published: December 2007

Abstract
This paper describes hydrate issues related to the design and success of a fast track development project for three Gulf of Mexico deep water subsea gas well completions. The project challenge required development of specific hydrate inhibition steps in order to minimize the occurrence of hydrates during well completion and flow testing due to cold mud line temperatures (45-55°F, 7-13°C), low reservoir temperatures (100-115°F, 38-46°C), and high bottom hole pressures (3,000-4,000 psi., 21-28 MPa.).
Basic hydrate formation theory and prediction were reviewed and integrated into a hydrate prevention program for the completion and testing program for this project. Hydrate prediction utilized temperature and pressure prediction modeling, overlay of potential events on hydrate equilibrium dissociation curves, and subsequent correlation to mud line temperature and pressure gauge measurements. Three areas of major concern for hydrate formation were during well flowback, shut-ins, and well kill. Hydrate inhibition included the use of inhibitors, and both surface and downhole injection systems involving various mixtures of glycol, methanol and IPA dependent upon the sequence of well events.
Blistering of Thermoplastic Materials Used in the Petroleum Industry
Authors: Jarrin Jacques , Dewimille Bernard , Devaux Elizabeth , Martin Joseph , Piques Roland 
Published: December 2007

Abstract
Experimental and theoretical results concerning the blistering of thermoplastic polymers used in the petroleum industry are described. Cells working with methane up to a pressure of 100 MPa have been equipped with an LVDT and temperature sensors to record the thickness variation, pressure and temperature of the samples during the tests. The results from the LVDT sensor have been used to model the different phases of the tests. The model described is based on the volumetric variations of the samples under gas pressure. This model estimates the Von Mises stresses in the materials during the tests. A comparison with the mechanical strength of the samples shows that the orders of magnitude are enough to predict the blistering of the materials tested.
A Review of Many Improved Recovery Methods
Authors: Crawford Paul B. 
Published: December 2007

Discussion of this paper is invited. Three copies of any discussion should be sent to the Society of Petroleum Engineers office. Such discussions may be presented at the above meeting and, with the paper, may be considered for publication in one of the two SPE magazines.

Abstract
During the past 20 years members of the petroleum industry have proposed more than petroleum industry have proposed more than fifteen new or novel recovery methods for increasing the ultimate oil or gas recovery. This paper is a general review of these new methods. A simple description of the new and improved recovery processes and their range of application is presented.
The methods discussed include wet combustion, forward combustion, reverse combustion and combustion with fuel injection. The miscible process of high pressure gas, enriched gas and LPG slugs, are covered. Use of micellar solutions, alcohol and foam flooding is covered.
The application of atomic bombs for well completions is discussed.

Introduction
A new oil recovery method was field tested near Throcknmorton, Texas approximately 35 years ago. The new method of steam flooding was to launch thermal oil recovery methods on their way. It seems that very little work in new oil recovery methods was underway until following World War II. At that time oil recovery by insitu combustion, steam drives and miscible high pressure gas recovery programs occupied considerable interest in some of the research laboratories.
At the present time thermal oil recovery takes on many different forms of operation, steam drives, hot water floods, forward combustion, forward wet combustion reverse combustion, combustion with fuel injection, combustion followed by waterflooding are all different aspects of the thermal recovery portfolio. Steam soaking should be included portfolio. Steam soaking should be included since it has been demonstrated to be a process which will increase the ultimate oil recovery method in economic times. In a similar manner miscible displacement now includes five different processes.
The purpose of this paper is to review a large number of these new recovery methods and provide an indication of their likely range of application.
A Novel Process for Profile Control in Thermal Recovery Projects
Authors: Morgenthaler L. N. , Schultz H. A. 
Published: December 2007

Abstract
Gels formed by crosslinking block copolymers have been developed for control of steam injection profiles in Shell’s thermal recovery projects in California. The combination of temperature dependent crosslinking and excellent thermal stability exhibited by these gels has been exploited to improve steam injection profiles with greater success and at lower cost than achieved with conventional profile control methods. Laboratory studies of gelation rate and gel strength to evaluate formulations for field application will be reviewed. More than forty successful treatments have been performed to date and validated using injection profile surveys. In every well, steam injection into the treated interval has been eliminated. Payout time, based on steam cost savings alone, has averaged less than two months.
Super Thick Fluids Provide New Answers To Old Fracturing Problems
Authors: Alderman E.N. 
Published: December 2007

Abstract
Extremely viscous fracture fluids have provided a new tool for stimulation of wells provided a new tool for stimulation of wells which previously have not been considered good candidates for conventional fracturing techniques. Soft sands and more permeable formations are the primary targets for the super thick fluids, but they have also performed well in retreatments and other performed well in retreatments and other applications.
Super thick fluids function by creating wider fractures and providing better prop penetration of the reservoir. The extremely penetration of the reservoir. The extremely high injection rates and large volumes of present treatments are not required. present treatments are not required. This paper will discuss the various oil-base and water-base fluids currently available. A theoretical comparison of fracture area, conductivity increase, and productivity increase obtained by conventional and super thick fluids under similar conditions is presented. Comparative field results of conventional and super thick fluids are also shown.
Introduction
A brief history of hydraulic fracturing fluids since the inception of fracturing in the early 1950's might be summarized as follows:
High-viscosity gelled oils and emulsions Refined oils Lease ails, water and low-viscosity, gelled oils Gelled water
In the early days of fracturing, viscosity was required to achieve fracturing efficiency. Pump rates were low and friction pressures were high. pressures were high. With the introduction of early day fluid loss additives, less viscous refined oils were successfully used. Pump rates were still limited by high friction pressures and pumping equipment. pumping equipment. Improved fluid-loss additives and pumping equipment led to an era of fracturing pumping equipment led to an era of fracturing with even lower viscosity fluids, such as lease oils, water and low-viscosity gelled oils. Pump rates increased because of the lower friction pressures.
The introduction of gelled water systems, with the natural properties for friction reduction and fluid-loss control started another era continuing even to date. The gelling materials, guar gum, cellulose derivatives or snythetic polymers have almost completely replaced treatments with oil-base fluids.