bluuebunny/crossref_metadata_2025_split huggingface dataset:
Dale/Coteau/Bluell Development and Economics, Burke County, North Dakota
Authors: Ausmus G. H. , Borchert R. N. 
Published: December 2007

ABSTRACT
Mississippian age formations have been an historic exploration objective in the Williston Basin. In the period between 1980 and 1987, over 300 wells were drilled in the study area, most of which tested the Dale, Coteau, or Bluell subintervals of the Mission Canyon formation.
This review of development in central Burke and northwest Ward counties was undertaken to evaluate the past and future economics of this exploration objective. Specifically, the reserves discovered by 1980-1987 Mission Canyon development were quantified, and the reserves required to reach minimum historic and present investment hurdles were determined. Comparison of past development to the historic investment hurdles showed that one-third of the 134 completed wells were profitable. Correlation of profitable well locations to regional geologic structure revealed that the profitable wells generally produced from traps with the greater degree of transverse structural closure. Ancillary topics relating to study area geology and shallower Charles formation reserves were also addressed.
On-Site Computer Monitoring of Foamed Stimulation Fluids
Authors: Baumgartner S. A. , Mack D. J. 
Published: December 2007

ABSTRACT
Computerized monitoring of hydraulic fracturing treatments has been an accepted practice for several years. Not only can a continuous record of the treatment parameters be made, but the real-time bottomhole treating pressure can be determined without the use of a reference string or bottomhole pressure tool. However, to calculate the bottomhole treating pressure, the friction pressure of the fluid or slurry must be determined. For conventional, incompressible oil and water-based fluids friction pressure is a straightforward calculation since rate and proppant concentration are the main considerations. The friction pressure for foam fracturing fluids requires a more complex solution.
A computer van was used to monitor carbon dioxide and nitrogen foam treatments incorporating a reference string or bottomhole pressure tool. The following parameters involved in the calculation of bottomhole treating pressure were examined in this study: injection rate, addition of proppant, effect of proppant on slurry friction pressure and foam hydrostatic head pressure. This paper presents a technique which allows the bottomhole treating pressure to be calculated without the use of a reference string or bottomhole pressure tool. The calculation of bottomhole treating pressure for a foam treatment incorporates a technique to correct the hydrostatic head pressure of carbon dioxide and nitrogen foams. In addition, the different effects of proppant addition on friction pressure between nitrogen and carbon dioxide generated foams are discussed.
Practical Application of a Reservoir Model to EOR: Lone Cedar (Minnelusa) Unit, Campbell County, Wyoming
Authors: King W. A. 
Published: December 2007

ABSTRACT
The Lone Cedar Field waterflood feasibility study had the advantage of having a complete set of logs, cores, core tests, fluid tests, reservoir pressure tests and daily production history on all producing wells. In addition the field was small enough to simulate on a personal computer.
The data was organized, calculated, summarized, compared, plotted, and prepared for the simulator using many computer generated spreadsheets. A three dimensional-three phase black oil simulator and a two dimensional polymer simulator were used to design the polymer augmented waterflood.
Accurate Design of Fracturing Treatment Requires Conductivity Measurements at Simulated Reservoir Conditions
Authors: McDaniel B. W. , Parker M. A. 
Published: December 2007

ABSTRACT
Recent fracture conductivity testing in the laboratory has achieved a new degree of realistic simulation of reservoir fracture conditions. Many investigators are now attempting to develop more accurate testing procedures. At least two laboratories have published data where conductivity tests have simultaneously included the effects of gel filter cakes, formation core effects, and extended test times at representative reservoir stress and temperatures. In this paper, work published in 1986 and 1987 is reviewed, and additional conductivity data with gel filter cakes are presented. Data showing the result of varying the proppant concentration inside the fracture from 0.75 up to 2.8 lb/ft2 are presented for the first time, showing that the effect of proppant concentration can not be neglected.
The economic success of hydraulic fracturing treatments depend on obtaining sufficient fracture conductivity within the proppant bed. This is illustrated by using a fracture design simulator to model the resultant propped fracture geometry and proppant distribution. By incorporating laboratory measured conductivity values (where gel filter cakes are present) these simulations show the importance of having realistic conductivity data when trying to optimize the treatment design.
Successful High Angle Completions, Cementing, and Drilling’s Impact
Authors: Fontenot J. E. 
Published: December 2007

ABSTRACTSuccessful well completions are the key to exploiting the potential benefits of high angle/horizontal drilling. Successful primary cementing is vital to completion success. Cementing success is often jeopardized by the wellbore created during the drilling process. This paper unfolds this dilemma and takes a look at what must be done to overcome it.
Application of Laplace Transformation to Elliptical Flow in Naturally Fractured Reservoirs: Part II-Field Applications
Authors: Okoye C. U. , Oyefodun A. , Matese J. J. , Hayatdavoudi A. , Ghalambor A. 
Published: December 2007

ABSTRACT
In part II of this study, we present the application of the unsteady state solutions to fluid flow in naturally and or vertically fractured reservoirs whose internal boundaries are assumed to be ellipticaliy shaped. Type curves generated using solutions to unsteady-state elliptical flow equations are used to analyze several published field pressure data for parameters such as permeability, skin factor, wellbore storage and fracture length.
The field data analysis results show close agreement with results obtained using other reservoir flow geometries such as radial or linear.
A Unique Wireline Re-Entry System for Seafloor Wells at Kepiting Field, Indonesia
Authors: Kadi I. , Wybro P. G. , Rodriguez F. H. 
Published: December 2007

ABSTRACT
This paper presents the work performed by Conoco Indonesia Inc. in developing and testing a unique re-entry system for wireline work on two seafloor wells in 295 feet of water at Kepiting Field in the Natuna Sea of Indonesia. This system does not require the use of a floating drillship for conventional wireline work in a seafloor well.
The main components are:
A 240 foot buoyantly tensioned steel seafloor riser A surface buoy which connects temporarily to the seafloor riser and also supports an above water work platform for the wireline lubricator assembly A set of strategically located permanent workboat moorings A workboat arranged to serve as the wireline unit's operating platform and to provide all support services.
This paper discusses the components, installation and performance of this unique wireline re-entry system.
Effects of Perforation Flow Geometry on Evaluation of Perforation Flow Efficiency
Authors: Liu Z. , Peden J. 
Published: December 2007

ABSTRACT
This paper presents a study on effects of perforation flow geometry on the evaluation of the flow performance of perforations. From data obtained in the laboratory serious deficiency and poor accuracy were identified in exploring the linear perforation targets recommended by API RP 43 Section II for the evaluation of the flow performance of perforations. This discredits the validity of the procedure and poses doubt to the correctness of applying API RP 43 results to the downhole conditions. The work suggested that perforations with radial flow configuration should be utilised in such an evaluation.
The Challenge of Thin Oil Development: A Case Study
Authors: Prasser R. S. 
Published: December 2007

ABSTRACT
The Snapper field, which is located in Bass Strait, offshore south-eastern Australia, contains a large gas reservoir, the "N-1", with an 8 metre "pancake" oil leg. While Snapper was developed primarily as a gas field, initial work has concentrated on maximizing oil recovery prior to eventual large scale gas production. Phase I development was undertaken during 1981-1983 with fourteen N-1 oil completions coming on-stream. Encouraged by the successful performance of these wells, a second drilling phase was undertaken during 1986-87, resulting in nine new oil completions.
Some gas production has been required to meet gas market demand. This production, from gas completions and-gas coning in oil wells, has caused the oil zone to steadily rise. Over the next few years, workovers in many of the wells will extend production as the column continues to rise.
This paper examines the highly variable performance of the mature Phase I wells and the early performance of the Phase II wells. This will assist other operators in planning similar, thin oil developments.
Handling of Liquid Holdup in Duyong Two-Phase Flow Pipeline System
Authors: Saad M. R. , Singh B. 
Published: December 2007

ABSTRACT
The paper deals with the handling of liquids in the multi-phase flow pipeline system within Carigali's Duyong Offshore Gas Complex and the Onshore Gas Terminal, in Kerteh, Terengganu. The data and operations experience gathered necessitate changes to the operating procedures originally identified during the design phase. This is to ensure more efficient handling of liquid hold-up in the pipeline during low gas flowrates.
The Study on Phase Behaviour of the Flowing Fluid in Tubing and its Application
Authors: Wang S. H. , Wu C. I. 
Published: December 2007

ABSTRACT
In order to minimize the tubing corrosion during production in a gas well, it is necessary to determine the factors such as wettability of tubing and critical erosional velocity etc. for the design of tubing corrosion prevention. The purpose of this work is to study the phase behavior of the production fluid in a production tubing in connection with the flowing velocity and wettability of tubing. Data from a CO2-rich offshore gas well of Taiwan are analyzed by a procedure developed in this study. It is shown by our calculation that the tubing in the well should not be corroded seriously during production because the tubing inner wall is oil-wet and the flowing velocities are much less than the critical erosional velocities.
Using Short-Term Pressure Buildup Tests for Reserves Estimation in Tight Gas Reservoirs
Authors: Sullivan S. A. , Poston S. W. , Piper L. D. 
Published: December 2007

ABSTRACT
Average reservoir pressure must be known when material balance equations are used to determine gas in place. Most pressure data available for material balance analysis comes from single point tests (static bottom hole pressure tests). Unless the reservoir has been shut-in long enough for the pressure in the reservoir to stabilize there is no direct means of determining the average reservoir pressure.
A method has been developed to estimate gas in place in volumetric gas reservoirs using transient pressure data. The method is similar to the isochronal flow test. Pressure data recorded at a specific shut-in interval is collected during a portion of the producing life of the reservoir. A p/z plot is constructed using this pressure data and the corresponding production data. The p/z curve will plot as a straight line with a slope similar to the stabilized p/z curve. However, this nonstabilized p/z curve will be shifted slightly downward from the stabilized p/z curve. Gas in place can be estimated by drawing a line parallel to the nonstabilized p/z curve through a point on the stabilized p/z curve, such as pi/zi. This new line is extrapolated to the point of intersection on the (Gp) x-axis.
This analysis procedure was tested with production data simulated for a single well reservoir model with and without wellbore storage distortion. The procedure was also tested with production data simulated for a hydraulically fractured well model. The results indicate this method can be used to estimate gas in place within a margin of error acceptable for most engineering purposes.
Gas Production Outlook and Technological Progress: European Problematics and Answers
Authors: Valentin E. P. , Valais M. R. , Champion D. J. 
Published: December 2007

ABSTRACT
Western Europe is far from lacking in natural gas. Its gas reserves are much greater than its oil reserves with regard to their energy content, and its gas production covers nearly three-quarters of its own needs, as opposed to only one-third for crude oil. Western European gas reserves are thus an important asset in the security of its energy supplies.
However, most of the increase in European gas reserves over the last fifteen years has come from offshore discoveries, mainly in the North Sea. This zone now contains 60% of the proven reserves and accounts for nearly half of gas production in Western Europe.
This trend will continue in the coming decades, with increasing difficulties in the development and exploitation of new resources, whether due to the water depth or to the increasing distance between consumption regions and recent discoveries. Therefore, the new generation of fields in the North Sea will necessarily call for new technological developments far in advance of the techniques now mastered.
The experience gained during the development of giant fields (Frigg, Troll) together with the studies carried out for the exploitation of marginal fields make up the basis for current research routes, which have been redirected in keeping with the economic situation. In addition to the optimization of proven concepts aiming at greater process integration, new technological developments will aim at both multiphase concepts and subsea implementation. The production of "frontier" gas resources and hence the development of new technologies are the price that Europe will have to pay to limit its dependence on gas imports.
A Predictive Model for Analyzing Erosional Velocity and Corrosion Effects Enhances Optimized Production of a Gas Well System
Authors: Farshad F. F. , LeBlanc J. L. , Root P. J. 
Published: December 2007

ABSTRACT
As depth increases, so do reservoir pressure and temperature and the mole fraction of carbon dioxide and hydrogen sulfide in the reservoir gas. Furthermore, it is becoming more and more desirable for the operators to produce gas at high flow rates. These factors result in an increase in the corrosiveness of produced fluids and the percentage of wells with corrosion problems. Today, it is estimated that over 50% of the producing gas wells in the U.S. are produced under conditions conducive to corrosion (corrosive wells).
Corrosion costs the petroleum industry more than $900 million annually. This includes production down-time, chemical treatment costs, material replacement costs, and increased workover costs caused by additional fishing time needed to retrieve parted tubing and repair damaged casing. Severe downhole corrosion problems may even force the abandonment of a well and the drilling of a new well.
The objective of this paper is to show that the economic development and production of these wells dictates consideration of three separate but related subjects: Total optimization of the production systemLimitation of pressure drop through the gravel packConsideration of erosional velocity
This study will show that the maximum production rates possible from these wells are usually restricted by the following limiting design parameters (1) pressure drop through the gravel pack (for a gravel packed well) and (2) the erosional velocity. Proper evaluation of these critical areas can extend the life of the production tubing in a corrosive well six to seven-fold.
Although this paper is addressed specifically to corrosive wells, the production optimization techniques shown can be applied to almost any other gas production system.
An Integrated Gas Transportation Management System
Authors: Hansen J. A. 
Published: December 2007

ABSTRACT
Today's world of gas brokers, spot markets and interruptible service is not conducive to the monthly cycles of billing and customer reconciliation of imbalances which supported the business of transporting gas for large, established, long-term transportation customers.
Today's gas transmission company must be able to monitor, control, and report transportation business within shorter time constraints. Traditional divisions between real-time pipeline control and custody transfer billing must be removed and computer systems supporting these functions must reflect these business changes.
GSAM is an integrated computer system designed to support real-time and custody transfer transportation management. Through the integration of meter facility, customer, transportation agreement, SCADA, gas composition, and custody transfer volume data, daily monitoring of customer activities and monthly calculations for commodity billing are accomplished to provide pipeline system and customer imbalance control.
In order to function in the deregulated gas industry in North America and remain competitive, gas transportation companies need to not only automate but integrate traditionally segregated areas of real-time pipeline control and custody transfer billing. NOVA Corporation of Alberta is meeting this challenge with a gas transportation management computer system, GSAM, integrating the Gas Supply and Measurement areas.
Furan Resin Process Replaces Workovers in Gas Storage Reservoirs
Authors: Weaver J. D. , Morgan J. A. 
Published: December 2007

ABSTRACT
A furan resin process has been successfully used to stop sand production in underground gas storage wells used by the Illinois Power Company.
The resin process consolidates formation sand into a matrix which is permeable to gas flow but screens sand out of casing perforations. Sand produced with gas can severely damage production equipment, enlarge perforations in the casing, and plug wells so that injection and withdrawal are prevented.
This paper presents a discussion of furan resin characteristics and applications for which it is suited. Treatment methods are detailed and treatment sequences presented. Case histories given for three wells show up to 13 years of gas injection into and sand-free gas withdrawal from storage wells that had previously produced enough sand to stop injection/withdrawal and to ruin valves and other production equipment. Storage wells completed initially with the furan resin process or recompleted after producing sand have required no workovers during the several years since treatment with the resin.
Single-Phase Simulation of an Aquifer Gas Storage Field
Authors: Damle A. S. , Berry R. M. , Kothari K. M. 
Published: December 2007

ABSTRACT
In an aquifer gas storage field, the gas/water boundary or transition zone expands and contracts cyclically due to the cyclic injection and withdrawal of gas in the field. The physical pore volume occupied by the gas phase thus changes with time. Although this change is cyclic, it is usually not in phase with respect to the gas injection and withdrawal cycle due to relatively slow response of the aquifer. The two phase (gas-water) system in aquifer gas storage field can be simulated using a single phase simulator, provided accurate predictions of the gas phase pore volume can be made as a function of gas injection/withdrawal rate and schedule. The established procedure for predicting gas/water boundary movement based on influence functions and the principal of superposition is tedious, time consuming and requires field history data from its early development stages.
This paper presents an alternative approach based on an equilibrium pore volume concept. An equilibrium pore volume at a given time may be defined as the pore volume that will be occupied by the gas in storage at that time if brought to the equilibrium aquifer pressure. At any given time, the actual pore volume occupied by the gas phase may be different than the corresponding equilibrium pore volume; and the difference provides the driving force for the water movement. This approach was successfully used in the analysis of data from an existing aquifer storage field. This concept for predicting gas/water boundary movement was incorporated in a reservoir simulation model to carry out a single gas phase simulation of an existing aquifer gas storage field. The field history was accurately predicted by this simulation procedure. This approach is simple, easy to incorporate in a simulator code, and can utilize current operating history data to obtain necessary model parameters.
Natural Gas From Low Permeability Formations
Authors: Kuuskraa V. A. , Haas M. R. 
Published: December 2007

ABSTRACT
This paper discusses the technology challenges and economically recoverable natural gas from three low permeability sources: tight gas sands, methane from coal seams and fractured, organically rich Devonian age shales. It discusses the nature of the low permeability resources and the technologies being developed by the Gas Research Institute (GRI), the Department of Energy, and industry. The paper contains three case studies where the application of improved technology has led to lower cost gas recovery. It concludes with an overview of the economic potential of gas reserves from low permeability formations.
There are two major themes of the paper: first, in the geologically most favorable reservoirs, natural gas is already being economically produced from low permeability formations; and, second, advances in gas extraction technology are essential for reaching the full potential of this resource.
Future Prospects of Saudi Natural Gas
Authors: Al-Fariss T. F. 
Published: December 2007

ABSTRACT
Saudi Arabia has about 3% of the total world reserves of natural gas. The total annual production of natural gas in Saudi Arabia is about 32 billion cubic meters. Most of this production is from associated gas to the crude oil production. It is also produced from gas fields such as Dammam, Hamur, Jawb, Lawhah, Maharah, Marjan, Shaybah, Zuluf, Abqaiq, Berri, Ghawar, Kidan and Qatiaf. In the past, associated gas were directly flared with little uses as fuel mainly in domestic appliances. It sometimes injected into oil reservoirs to help in oil production. It is often used in industrial purposes either as a source of energy in electricity generation, refinery fuel or in lime or fertilizer manufacturing. Nowadays, natural gas is considered the backbone of many petrochemical industry in the country. This paper will review the current utilization of Saudi natural gas with an insight look toward the brightful future.