bluuebunny/crossref_metadata_2025_split huggingface dataset:
Automatic Crude Oil Handling Through a Pressurized System from the Wellhead to the Refinery
Authors: Davis William B. , Truman Paul W. , Groeneman Austin R. 
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 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
Production from 51 wells completed in the three unitized formations of the Lost Soldier Field, Sweetwater County, Wyoming, is brought to a central point through individual flow lines. Here the fluids are directed through separate automatic well testing and oil treating facilities, one for each formation. After separation of oil, gas and water, the oil goes to pressurized surge tanks and then to lease automatic custody transfer units. There is one surge tank and one LACT unit for each formation. The oil is automatically transferred to the Sinclair Pipe Line Company for delivery to Sinclair's refinery at Sinclair, Wyoming, through a closed pipe line systems.
A central console provides:
supervisory control from the wellheads through the LACT units, well test and production data logging, and monitoring by activating alarms for abnormal conditions of flow, liquid levels, temperatures and pressures.
Fifteen months experience with automatic handling of crude oil through a pressurized system from the wellheads to the refinery at a rate exceeding 12,000 barrels per day of pipe line oil has revealed many advantages to all parties concerned. The advantages include:
Increased recovery of produced hydrocarbons and boosted gravities by the elimination of oil storage in atmospheric tanks both in production and pipe line facilities.
Early detection of pumping wellmal functions enabling repairs to be made before daily production is substantially decreased.
Quick and definite alarm reporting resulting in immediate repairs.
Reduced manpower requirements for gathering field data and operating valves, pumps, etc.
Provides printed well test and production data records.
Use of Mud Logging Data in Drilling Performance Analysis
Authors: Aarrestad T. V. , Tapper R 
Published: December 2007

Abstract
For a long time the mud-logging companies have provided the driller and drilling engineers with rather sophisticated computer systems for data presentation and some minor data processing, while drilling a well. The computer systems have also been available for office use both with a link to the on-site computers and as a post-processing data system.
Several systems are also available for well planning, ie well trajectory planning with or without a torque and drag model connected to the computer programme.
Each mud-logging company delivers its own special system for recording and analysing the data. In order to evaluate data from the different service companies and extracting more information about the drilling process there is a need for a general system. A main-frame database system with additional software packages for statistical analysis and torque/drag calculations has been developed. The data from the mud-logging companies may then be read from the received tapes/diskettes and put into the multiwell database structure.
The Osprey Development - The Use of the Cluster and LBM Concept for Marginal Field Development
Authors: Wilson R. , Oakes N. E. D. 
Published: December 2007

Abstract
Having enjoyed considerable sucess with its high technology Central Cormorant Underwater Manifold Centre, Shell Expro has directed its attention towards simpler, low technical cost systems which can be applied to ‘fast track’ development of marginal prospects. One method of achieving these objectives is to utilise Xmas tree manufacturing techniques and resources, to provide solid block forged manifolds with suitable bores and end outlets to facilitate connection of cluster wells and transport pipelines. This Shell Expro concept, involving assembly, rather than fabrication processes, to construct the manifold and requiring minimal land testing, was developed by Cameron Offshore Engineering, and has been adopted as the basis for the eleven Well Osprey Development.
In its original form, the concept was a stack up of solid block forgings serving as production, injection and pigging manifolds, mounted on a single base. However as Shell Expro developed this approach, it was realised that significant operational advantages could be gained by separating the oil and water systems into two separate clusters, located within the span of a drilling / installation vessel's anchor pattern, but allowing (through repositioning of the rig within the same anchor pattern) concurrent sea bed operations to be carried out at each cluster.
Detailed design and manufacture of this system is now being undertaken by Cameron Iron Works for Shell Expro, with installation planned for spring and summer 1990.
Practical Problems in Well Testing Devonian Shale Gas Wells
Authors: Murtha J. A. , Lancaster D. E. 
Published: December 2007

ABSTRACT
This paper itemizes several problems that can occur when conducting pressure buildup tests on Devonian Shale gas wells. Although buildup tests conducted on Shale wells have the same objectives and use the same procedures as buildup tests run on other formations, certain characteristics of Shale reservoirs and their well completion methods make well testing complicated. Specific problems include not running the test long enough, encountering liquid in the wellbore, mechanical failures, communication failures, cleanup behavior following stimulation treatments, and surprises. We provide field examples and suggest remedies and means of avoiding some of the common problems.
Correlations of Interference/Pulse-Test Results With Tiltmeter Studies of Fractures Induced in the Chattanooga Shale
Authors: Locke C. D. , Salamy S. P. , Overbey W. K. , Yost A. B. 
Published: December 2007

ABSTRACT
Natural/induced fracture orientation and permeability anisotropy (Kx:Ky) are two critical parameters required for understanding highly fractured anisotropic reservoirs such as the case in the Devonian shales.
A detailed geologic/engineering test was performed on the Chattanooga shale in eastern and southeastern Kentucky. Early results of tiltmeter responses were correlated with pre- and post-stimulation interference and pulse test results. Tiltmeter responses were corrected for uplifts induced by pressure transient during the frac treatment. In addition, corrections were applied to pulse test results for skin and wellbore storage.
Early studies of the pre- and post-stimulation interference tests indicated major permeability trends of N18°E and N32°W, respectively. In addition, a post-stimulation permeability anisotropy of 20:1 was calculated. Results of initial tiltmeter pressure response analyses indicated an induced fracture orientation of N30°E and a possible second orientation of N30°W.
CO2 Mobility Control by Carbonate Precipitation: A Modeling Study
Authors: Aminian K. , Ameri S. , Cunningham L. E. , Watts R. J. 
Published: December 2007

ABSTRACT
CO2 flooding is the most promising enhanced oil recovery method. However, the CO2 tends to bypass a high percentage of the oil in the flood pattern causing early breakthrough and low recovery efficiency. An unconventional approach for CO2 mobility control is to modify the reservoir permeability profile by chemical precipitation. This method employs water soluble salts of earth alkali group that react with CO2 to form carbonate precipitate. Chemical precipitation occurs in the high permeability zones and the subsequent fluid flow will be diverted to unswept portion of the flood pattern. The overall objective of this study has been to evaluate the feasibility of carbonate precipitation to improve the recovery efficiency by reducing CO2 mobility. The earlier experimental studies have shown that carbonate precipitation can alter the core permeability under reservoir conditions. In addition, the relative permeability measurements have revealed that precipitation reduces the gas permeability in favor of liquid permeability. This paper reports the preliminary results of modeling of the process for field application. A numerical reservoir model has been utilized to study the effect of precipitation on sweep efficiency and oil recovery.
Effect of Various Additives on the Properties of the Clarified XC Polymer System
Authors: Nguyen H. T. , LaFontaine J. M. 
Published: December 2007

Abstract
Recently, a clarified XC polymer has been introduced to the petroleum industry and extensive studies have been performed to determine the effectiveness of this polymer as a viscosifier for gravel packing fluids. A good gravel packing fluid must have good gravel carrying capacity, good fluid loss or leakoff, controllable viscosity reduction, and minimal damage to the formation. XC polymer was evaluated to have good gravel carrying capability at lower polymer loadings, 36 - 48 pptg (pounds per thousand gallons), than the standard HEC polymer, 65 90 pptg. The XC polymer also displays good leakoff characteristics which are essential to gravel placement in perforations. However, XC is an anionic polymer, it is sensitive to chemical additives. Therefore, this study includes the effect of various common oilfield additives on the properties of the clarified XC polymer system. Common oilfield additives are salts, sequestering agents, surfactants, clay stabilizers, acids, bases, biocides, defoamers, etc. The results showed that the leakoff characteristics, the effectiveness of gel breaker and the formation damage potential of the XC polymer system were greatly affected by these chemical additives. Applications of any chemical additives to the XC polymer system without testing could result in severe damage to the formation. This paper discusses and presents data that shows the effect of various chemical additives on the performance of the clarified XC polymer system as a gravel packing fluid. Comparison between the XC polymer system and the conventional HEC polymer system will also be presented in the process.
Completion Fluid Invasion Simulation and Permeability Restoration by Sodium- and Potassium-Based Brines
Authors: Azari M. , Leimkuhler J. 
Published: December 2007

Abstract
A laboratory study was performed to simulate completion fluid invasions into large Berea and Casper sandstone cores. Permeability was initially stabilized with a 4% NaCl reference brine, then flow direction was reversed through each core with sodium and potassium completion brines. After a stabilized permeability was obtained under invasion conditions, the reference brine was flowed again through the cores to simulate production after completion.
In Casper sandstone the permeability stabilized 5% higher than the originally established level for the KCl completion fluid, while it only increased 2% with NaCl brine. No increase in permeability was obtained in Berea cores with either KCl or NaCl completion fluids.
Experiments were also performed to determine the effects of completion fluid and flow reversal on stabilizing the permeability of a formation with clay dispersion damage. Results of these studies indicate that for each sandstone a threshold KCl brine saturation exists (10% in Berea and 5% in Casper) above which the illite clay lattices collapse around the exchanged K+. Once a formation is exposed to a KCl brine saturation higher than the threshold saturation, the excessive clay dispersion and swelling damage of the rock is inhibited even after the formation is exposed to much lower salinity levels.
The Comparative Effect of Petroleum Taxation on Field Development
Authors: Allinson W. G. , Williamson M. 
Published: December 2007

ABSTRACT
Petroleum royalty, tax, State participation and production sharing regimes have a significant effect on field development economics and the decision to explore for and develop oil and gas discoveries.
The paper examines and compares the effect of taxation/production sharing regimes on hypothetical but representative field developments in Australia, Papua New Guinea and Indonesia with the aim of demonstrating how these regimes affect the investment decision and corporate strategy.
The paper covers the following:-
A description is given on the petroleum royalty, income tax, surplus profits, State participation and production sharing regimes for petroleum developments in Australia, Papua New Guinea and Indonesia.
The results of economics analyses of the same hypothetical field development with the application of the different regimes are presented and discussed. These isolate the economic effects of the major differences in the taxation/production sharing regimes in the different countries without regard to the different hydrocarbon potential or field characteristics appropriate to each country. The assumption of a common environment and prospectivity is then relaxed in a discussion of the effects of tax in the context of exploration and field development in the specific geological, economic and political conditions of the countries in question.
Broad conclusions are made of the effects of taxation/production sharing regime on oil company profitability in the countries selected and how they affect company strategy and Government policy as part of a range of factors influencing their determination.
Uncertainty and Risk in Petroleum Exploration and Development: The Expectation Curve Method
Authors: Behrenbruch P. , Azinger K. L. , Foley M. V. 
Published: December 2007

ABSTRACT
Hydrocarbons are being recovered from ever greater depth and offshore in deeper waters. More marginal (offshore) projects are often only viable due to the use of new and innovative engineering solutions. Furthermore, these technically more advanced projects are being planned in today's volatile, economic climate where oil prices are relatively low and uncertain. It is therefore not surprising that project feasibility and economic analysis methods are becoming more elaborate, methods that take proper account of uncertainties and risks in all aspects of a project.
Statistical distribution methods have been in use since the early 1900's, but Monte Carlo methods were generally not applied until the 1940's, methods that were based on game theory of von Neumann and Ulam. While those early applications were mainly in science and some selective engineering areas as for example defence, wider technological use1 and business applications2 were not prevalent until the fifty's and early sixty's. Simple statistical methods used in petroleum engineering, in common use since the early sixty's, were generally replaced by full Monte Carlo methods in the seventy's, with recent, more elaborate calculation methods requiring considerable computer power, as for example in reserves calculations of the North West Shelf Gas Development3.
The expectation curve, also known as cumulative frequency distribution, S-curve or exceedance chart, may be the result of simple statistical frequency analysis or more comprehensive probabilistic (Monte Carlo) modelling. As will be described, the use of the expectation curve is a universal and powerful technique which allows for a quantitative appreciation of data in all areas of exploration and production, situations where variation and uncertainties in variables are of importance.
Risk can be considered to fall into two categories: situations which give rise to equipment failure or human error leading to a major accident, as for example the recent Piper Alpha platform disaster, and those situations which are related to uncertainty, the subject of this paper. A number of Australian examples are presented.
A Prediction Method for Conduction Heating of Reservoirs by Steam Injection
Authors: Satter Abdus 
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.
This paper was prepared for the 42nd Annual Fall Meeting of the Society of Petroleum Engineers of AIME, to be held in Houston, Tex., Oct. 1–4, 1967. 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 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
A method of reservoir heating involving heat conduction from a thin steam channel within the pay has been investigated. Solutions using a simplified heat flow model are provided to estimate steam injection rate, growth of steam zone and temperature distribution as a result of injecting steam into either a fracture or a thin section of the pay. Equations are also presented to obtain temperature distribution after termination of steam injection. Calculated results show the effects of injection rate, temperature, pay thickness, and well spacing.
The conduction heating process can be applicable for raising the entire reservoir to a moderate temperature in a relatively short time. Other advantages over the conventional steam drive are also discussed. It has been shown that a direct steam drive operation which degenerates into steam channeling through a thin section of the pay can be carried on as a conduction heating process.

Introduction
A direct steam drive process which requires that steam flows through the entire vertical section of the pay suffers from a number of disadvantages. A large quantity of heat is needed to move the steam front through a reservoir, especially with thick pay and high steam temperature. Heat losses into the under and overburden formation also retard the movement of the steam zone. Unless the well spacing is close and/or a very high steam injection rate is used, the project can be too long to be economic. In addition, many heavy oil reservoirs are unsuitable for the direct steam drive process because the oil viscosity is too high. While the oil viscosity in the hot water bank ahead of the steam zone is reduced, the interwell area or the region around the producing wells remains at the original reservoir temperature with no reduction in oil viscosity. Therefore, the oil production rate remains relatively low for a good portion of the project life.
A thermal recovery technique called conduction heating may overcome these disadvantages by providing a rapid means of heating a reservoir.
Cased-Hole Hydrocarbon Detection in the Permian Basin Using the Full-Wave Sonic Tool
Authors: Kessler C. , Sanders L. 
Published: December 2007

Abstract
The detection of hydrocarbons through casing in low porosity formations is extremely difficult using traditional log analysis techniques. Pulsed neutron logs are usually ineffective for saturation determination in this environment. At low porosities, the thermal neutron capture cross section, Σ, is dominated by the large volumetric effects of the matrix; therefore, the Σ-contrast between hydrocarbon- bearing and brine-bearing formations is generally small and virtually undetectable. Location of hydrocarbons through casing with dual-detector neutron tools is also difficult. Such tools respond primarily to formation hydrogen (which is found mainly in the pore fluids), and the effects of gas and low porosity on tool response are very similar. Sonic tools with conventional transmitter-to-receiver offsets are routinely run in cased holes in hard rock areas and can yield valid formation interval transit time (Δt) measurements when there is excellent cement bond. Under these conditions, cased hole Δt and neutron porosity measurements can be crossplotted for lithology identification and gas detection.
The Full Wave Sonic tool has been used successfully to detect hydrocarbons behind casing. In cased hole applications, this tool is free of many of the problems that plague sonic logging tools with conventional offsets. In other than perfect bonding situations, its longer offsets allow ample time for the casing and formation signals to separate, thereby permitting accurate determination of Δt. This is verified by comparisons of open and cased hole compressive and shear Δt measurements, Δtc and Δts. Additional test well data from an ultra-long- offset Full Wave Sonic tool that has an 18- foot (5.49-m) transmitter-to-first-receiver offset are presented to show this effect. To further expand the application of cased hole Full Wave Sonic data analysis to other than perfect bonding conditions, enhanced processing techniques employing time windowing and frequency filtering are available to reduce the effects of the casing signal.
This paper emphasizes field examples in which hydrocarbons were successfully detected using Full Wave Sonic data. The presence of a compressible pore fluid, such as gas or oil with dissolved gas, causes a reduction in an acoustic velocity ratio and an increase in the attenuation of the acoustic signal. The reduction in the velocity ratio is significantly greater than variations that may arise from slight lithology changes. Successful production of light hydrocarbons has resulted when zones were selected for completion based upon velocity ratio reductions and acoustic signal attenuation over intervals of sufficient length.
Network Modeling of Xanthan Rheology in Porous Media in the Presence of Depleted Layer Effects
Authors: Sorbie K. S. 
Published: December 2007

Abstract
The mathematical description of the rheology of xanthan biopolymer within a porous medium - referred to as in situ rheology - is important if we wish to model oil displacement processes using this polymer. Most workers find that the in situ behaviour of xanthan is qualitatively quite similar to that of the bulk fluid. However, in recent years, others have found clear evidence for a slip-like effect on the in situ apparent viscosity of xanthan. The main finding of this latter body of work is that, in the lower pseudo-Newtonian flow regime, the in situ apparent viscosity is lower than that of the bulk viscosity. This has been interpreted as being due to a layer close to the pore wall from which polymer macromolecules are excluded. This boundary layer is depleted in polymer and therefore has a lower viscosity than the injected fluid which leads to the slip effect. This surface exclusion effect is also thought to be responsible for the velocity enhancement of the polymer molecules relative to tracer species which is sometimes attributed to the alternative mechanism of inaccessible pore volume.
Previous work on the mathematical analysis of the depleted layer effect has used very simple models for single capillary flow which only apply in the low flow pseudo-Newtonian regime. In this paper, we present an extension of this previous work in which we first solve the full hydrodynamic problem within a single capillary including depleted layer and shear effects. The results from the single tube case are then used within a network model of the porous medium. These network calculations allow us to make certain predictions on the macroscopic consequences of the depleted layer on the experimentally observed apparent viscosity behaviour. A number of specific findings are presented but the main two predictions from the network calculations are that (i) the drop in apparent viscosity is significant even for fairly modest depleted layer thicknesses and (ii) the slope of the apparent viscosity vs flow (shear) rate curve in the shear-thinning region is less steep (apparent power law index is higher) in the presence of the depleted layer than in its absence. In both cases, the predicted magnitude of the effect is such that it should be clearly observable experimentally.