bluuebunny/crossref_metadata_2025_split huggingface dataset:
Performance of Axial Electric Submersible Pumps in a Gassy Well
Authors: Sachdeva Rajesh , Doty D. R. , Schmidt Zelimir 
Published: December 2007

ABSTRACT
This is a continuation of the earlier work on the I-42B pump presented by Sachdeva1. The dynamic model developed earlier is extended to include axial geometries. Correlations are developed for CD/rb -- the only correlating factor required to complete the model. The performance of radial C-72 and axial K-70 pumps under gassy conditions is studied. Besides the dynamic model, a simple correlation (Model 2) for predicting the pressure rise per stage is also developed for the C-72, K-70 and I-42 pumps.
MEOR—Altamont/Bluebell Field Project
Authors: Streeb L. P. , Brown F. G. 
Published: December 2007

ABSTRACT
This paper presents a field application of microbial treating in the Altamont/Bluebell Field. The project demonstrates the use of microorganisms to treat high wax content crude oil to improve field operations, reduce chemical use, conserve lease fuel, increase production and enhance oil recovery.
The Feasibility of Using CO2 EOR Techniques in the Powder River Basin of Wyoming
Authors: Branting J. K. McDaniel , Whitman D. L. 
Published: December 2007

ABSTRACT
The feasibility of tertiary oil recovery by CO2 injection in fields located in the Powder River Basin of Wyoming was studied. The objectives were 1) to estimate the amount of tertiary oil that could be recovered by CO2 injection in the Powder River Basin of Wyoming; 2) to locate sources of CO2 for this basin; 3) to measure the potential demand for CO2 in this basin; and 4) to find the economic range of feasibility for CO2 utilization in this basin. The work was not intended to be a detailed analysis of the reservoirs in the Powder River Basin and their compatibility with CO2 injection, but rather, an attempt to get a rough estimate of the usefulness of CO2 in the Powder River basin.
Fracture Treatments in a Moderate-Permeability Sandstone: Converse IIA Formation, Lance Creek Field, Wyoming
Authors: Myers V. C. , Arnold L. L. 
Published: December 2007

ABSTRACT
This paper is a study of hydraulic fracturing techniques used in the Converse IIA reservoir in the Lance Creek field, Niobrara County, Wyoming. The Permian Converse formation is composed of interbedded dolomites, anhydrites, shales, and sandstones. In the Lance Creek field, the upper Second Converse section contains an oil-productive sandstone at an average vertical depth of 4600 ft. The pay sand, known as the Converse IIA, is from 15- to 35 ft thick; the average porosity and permeability is 9% and 5 md, respectively. With the depletion of the formerly-prolific Leo and basal Sundance zones below their economic limit, many Lance Creek wells have been recompleted recently in the Converse IIA zone.
To enhance production from this moderate-permeability sandstone, hydraulic fracturing treatments have been performed on most of the Converse IIA wells in the field. A unique situation exists in that fluid and proppant volumes pumped in the treated wells are similar, but fluid and proppant types are varied. In this paper, we evaluate the response of the reservoir to the different treatment materials and techniques that have been used. Conclusions on the relative success of the different treatment options is substantiated by comparing treatment and reservoir data to production and well-history data.
A Numerical Study of Coalbed Dewatering
Authors: Seidle J. P. 
Published: December 2007

Abstract
Unlike conventional reservoirs, the productive capacity of a coalbed is not immediately apparent. New coal wells typically produce at low rates and often exhibit low gas-water ratios. Only after a coalbed has been dewatered does gas rate begin to rise and water rate begin to fall. A numerical study was undertaken to investigate saturation and pressure behavior during the initial dewatering period and to develop methods to predict its duration. These simulations used typical coalbed and well properties encountered in Warrior and San Juan Basin coal wells. Behavior of gas saturation and pressure profiles during dewatering is discussed. It was found that, for engineering purposes, coalbed dewatering can be considered a constant pressure process. Two methods were developed to determine time and cumulative water production required to dewater a new coal well. The first method is based on the classical definition of pseudo-steady state flow, while the second method is based upon the gas-water ratio. Accuracy of both methods is discussed and a recommendations made for application to actual coal wells. Effective coalbed porosity is difficult to measure, but is necessary for reservoir engineering calculations and numerical simulations of coal well performance. Once a coal well has been dewatered, the gas-water ratio method developed here can be used to determine effective porosity. An example calculation is presented.
Coalbed Methane Well Production Forecasting
Authors: Soot P. M. 
Published: December 2007

ABSTRACT
A method (NWFuel Method) has been developed to predict the cumulative production from coalbed methane (CBM) wells. This Method has been developed from actual production data from over 1,500 wells in the Black Warrior and San Juan Basins. The technique involves ranking of individual wells against a series of generic production curves. These generic curves are based on computer simulations representative of the respective basins. The assigned "Rank" provides an indication of the amount of production anticipated from a given well over its lifetime. Both water and gas production are predicted by this Method. Although the Method is not precise for individual wells, it should be statistically significant for groups of CBM wells.
The technique involves ranking individual wells against a series of cumulative production curves. These generic curves are based on computer modeling of wells in the respective basin. It has been observed that most wells proceed along a given cumulative production curve, providing the basis for projecting future production.
Applying the Method in the Black Warrior Basin indicates that the average CBM well in that Basin will produce about 200 MMCF (5.7 million m3) in ten years. This is the result based on an evaluation of 641 wells which were on line before 1990. The San Juan Basin typically has a considerably higher production potential per well. An average for the entire Basin is not meaningful. The best and worst wells in that Basin vary in their reserves by two orders of magnitude.
The results from the NWFuel Method can be mapped. This allows one to associate production results with geological parameters. The subsequent result can enhance the exploration for new wells in a basin.
Modeling Coalbed Methane Production With Binary Gas Sorption
Authors: Arri L. E. , Yee Dan , Morgan W. D. , Jeansonne M. W. 
Published: December 2007

Abstract
A description of binary gas sorption on coal is developed and incorporated into a reservoir simulator for use in predicting primary and enhanced recovery of coalbed methane.
The sorption of methane-nitrogen and methane-carbon dioxide mixtures was measured at 115°F and total pressures of 500, 1,000, and 1,500 psia. A moist Fruit-land coal sample from the San Juan Basin of Colorado was used. The results showed that each gas did not sorb independently, instead both gases were competing for the same sorption sites. An extended Langmuir isotherm provided a reasonable correlation of the data.
A compositional reservoir simulator was modified using the extended Langmuir isotherm as the basis for the equilibrium relationship between the free and sorbed gas. The resulting formulation is functionally equivalent to a compositional representation using K-values expressed as a function of total pressure and the concentration of one component. The modified simulator was successfully tested for the cases of primary recovery of a single sorbing component and the enhanced recovery by nitrogen injection.
Laboratory Study of the Effects of Miscible WAG Process on Tertiary Oil Recovery
Authors: Zekri A. Y. , Natuh A. A. 
Published: December 2007

ABSTRACT
Misciblc gas flooding using carbon dioxide and natural hydrocarbon gases is currently being investigated as possible EOR process in a number of Libyan reservoirs. The major reason for selecting miscible gas flooding as an EOR process was because of the adaptability and possible gas availability at reasonable cost. C02 and hydrocarbon gases could achieve miscibility with a number of reservoir oils at current conditions [pressure] through a multi-contact miscibility process.
The main disadvantages of miscible gas flooding is the high mobility ratio so that the gases have the tendency to channel through the oil which results in by-passing much of the oil in the reservoir and low sweep efficiency. To solve this problem, a technique was tested consisting of alternately injecting small solvent [hydrocarbon gas or CO2] and water slugs. The slug of water reduces the speed of the solvent which results in reducing the chance of solvent fingering and improving the mobility of the system.
The main objective of this study is to investigate the effect of WAO RATIO on overall reovery of tertiary miscible flooding. Laboratory tests were conducted on three stacks of composite cores arranged in permeability descending order. The effects of lithology on overall performance was also tested.. The system studied in this work was an oil wet system. Tests were conducted in 3 ft. oil wet sandstone and carbonate rock cores. Cores utilized in this projcct were obtained from two Libyan reservoirs and arranged in desending order to form three composite stacks. Water and solvent were iinjected separately.
Operational Aspects of Drilling and Completing Horizontal Wells Offshore Abu Dhabi
Authors: Bowen J.F. , Hassan M.M. 
Published: December 2007

Abstract
Since June 1989, Zakum Development Company (ZADCO) has drilled and completed eight horizontal producing wells in Upper Zakum Field and one well in Umm Al Dalkh Field.
With numerous development drilling locations remaining in Upper Zakum Field, the potential for increased usage of horizontal techniques is significant. Most of the required production platforms are in place and most of the remaining slots are dedicated for medium and high departure wells. One high departure horizontal well with a horizontal section extending more than 9000 lateral feet from the platform has been successfully drilled and completed.
In addition, the potential to sidetrack numerous existing low/medium/high departure wells for horizontal drilling is significant. In fact, five of the nine horizontal wells drilled to date were reentry sidetracks and four were drilled from the surface.
The purpose of this paper is to present an operational overview of ZADCO's experience with horizontal wells. Topics of special interest include:the unusual horizontal well trajectories required offshore (i.e. high-departure wells),efforts to minimize top-hole doglegs to minimize torque and drag and reduce casing wear,a technical and economic comparison between sidetracking and drilling new wells,a discussion of current and future completion techniques, andstimulation techniques.

Introduction
Discovered in 1963, Zakum Field is the fourth largest field, and the largest offshore field, in the Middle East. Early development efforts focused on Lower Zakum Field. Development of Upper Zakum Field began in 1977.
Thus far, a total of 310 wells have been drilled and completed in the 465 square mile Upper Zakum Field, most of which are deviated wells with dual completions. More than one hundred infill wells remain to be drilled.
There are three distinct groups of limestone reservoirs in Upper Zakum Field, the Thamama I, II, and III. Well spacing ranges from 2500 to 5000 feet. Water injection was initiated in 1984 to maintain reservoir pressure and maximize profitability.
ZADCO first studied horizontal drilling in 1988 as a potential means to optimize the development of Upper Zakum Field. Operating on behalf of Abu Dhabi National Oil Company and in conjunction with Abu Dhabi Marine Operating Company, ZADCO drilled the first horizontal well in the Arabian Gulf in 1989, in Upper Zakum Field.1
The advent of horizontal drilling technology has provided ZADCO with a unique opportunity to develop Upper Zakum Field using state-of-the-art technology. Initial results of the horizontal trial program have been excellent from both operational and reservoir management viewpoints. Present plans include increased usage of horizontal techniques, including dual horizontal producing wells and horizontal injection wells.
Application Of Horizontal Drilling To Alleviate Water Slumping
Authors: Kader S. A. , Hafez H. H. 
Published: December 2007

ABSTRACT
Within ADCO, horizontal drilling has been used successfully to enhance well productivity, injectivity, and to reduce water coning in some production wells. This paper presents a case history of how horizontal drilling has been used to reduce the effects of water slumping between psuedo-reservoirs, resulting in reduced water cut and increased productivity; and reservoir simulation efforts to match and predict well performance.
A short radius horizontal hole of 850 ft length was drilled in the dry Thamama B Lower pseudoreservoir in an existing well in the Asab field, and succeeded in reducing water slumping from the wet upper pseudo-reservoir. This resulted in a reduction in the water cut from 20% to less than 1% with a five fold increase in the well productivity. A simulation model of a reservoir element was constructed with local grid refinement to represent the horizontal well. Past performance of the well was matched and the model was used to predict future well performance.
Logging and Stimulating Horizontal Wells Offshore Abu Dhabi
Authors: El Sebai H. D. , Ghneim G. J. 
Published: December 2007

_
This paper was a repeat presentation at the SPE Middle East Oil Technical Conference and Exhibition held in Bahrain, 3-6 April, 1993.

Abstract
During 1991 ADMA-OPCO planned to drill two horizontal producers. It was also planned to measure the petrophysical properties of the horizontal sections by Logging While Drilling (LWD) and by conveying conventional open hole logs on drill-pipe under Tough Logging Conditions (TLC). Each well was suggested to be logged by different LWD contractor.
Bullheading the acid into the formation is very inefficient and not expected to stimulate more than a few feet of the horizontal section as the acid tends to spend near the top when it contacts the limestone formation. Thus, to allow uniform distribution of the acid in the horizontal sections, the coiled tubing was used to pump the acid into the formation while pulling ft out.
Batches of foam diverters were pumped at regular intervals to ensure proper diversion of the acid. During the pumping sequence, a diesel oil was pumped down the coiled tubing X production tubing annulus to prevent the injected fluids from travelling up the hole by creating a back pressure on the upper sections.
Part one of this paper reviewed the logging operations and compared the results of the two LWDs with the open hole logs and with the core analysis results.
Part two discussed the operational and efficiency aspects of stimulating an offshore horizontal well.
Well Testing of A Fractured Well in a Multilayered Bounded Square
Authors: El-Sayed Osman Mohamed 
Published: December 2007

ABSTRACT
This study presented the pressure behaviour of a well located in multilayered bounded square and crossed by a vertical fracture (uniform flux or infinite conductivity). It was found that pressure function and its derivative and fractional flow from different layers are mainly controlled by the fracture extension into the formation. The effects of transmissibility and storativity on fractural flow and pressure derivatives are significant. Such effect on pressure functions are insignificant. Therefore, type curves of pressure functions can not be used in evaluation reservoir characteristics while those of pressure derivative can be used for this purpose. The nature of the fracture was found to have minor effects on different parameters included in this study. It was found that type curves of buildup pressure function can be used only for very small values of fracture extension and production time.
Environmental Planning through Risk Assessment
Authors: Cayias J. L. , Gordon R. D. 
Published: December 2007

Abstract
The risk assessment process can be used as a strategic planning tool to manage environmental risks in the oil industry. Risk assessment allows for evaluation of clean up levels at contaminated sites based on reducing human health risk to acceptable levels while selecting the most cost effective remedial approach. The use of this approach gives consistency to the management of environmental risks and allows the risk manager to allocate resources so that they will have the greatest impact on reducing risk to human health. This paper discusses the risk assessment process and uses two examples to show how it can be applied to solve environmental problems in the oil field.
New Method for Better Control of Cement Performance in High-Temperature Wells
Authors: Nelson E. B. , Casabonne J. M. 
Published: December 2007

ABSTRACT
Deep, hot wells present special cement-system design challenges. Among them is the simultaneous achievement of adequate slurry-placement time and acceptably short waiting-on-cement (WOO time. This paper describes a new slurry-design method and a novel retarder that address this problem. To reduce the potential of job failure and to save rig time, the new design method relies more upon the static temperatures at the top (ST @ TOC) and bottom (BHST) of the cemented interval. Traditionally the bottomhole circulating temperature (BHCT), which is often not accurately known, is the most important design criterion. The new technology allows uncommonly long thickening times, providing an increased safety margin, without sacrificing rapid compressive strength development.
Treatment of Production Tank Bottom Sludge by Composting
Authors: Nordrum S. B. , Fyock Leroy , Findlay Margaret 
Published: December 2007

ABSTRACT
Treatment of oily waste by composting was demonstrated at a Chevron facility. The full-scale operation involved mixing sludge with bulking agent and fertilizer, and aerating the mixture using a tractor-mounted auger. Ninety-seven percent of the petroleum hydrocarbons were destroyed in 41 days, based on quantitation of major constituents by gas Chromatograph.
A Laboratory Study of Cement and Resin Plugs Placed With Thru-Tubing Dump Bailers
Authors: White W. S. , Calvert D. G. , Barker J. M. , Bour D. L. 
Published: December 2007

ABSTRACT
Laboratory experiments were conducted to study the factors that influence the successful placement of cement and resin plugs using thru-tubing dump bailers. The five-phase study included: (1) cement slurry design, (2) full-scale visual tests, (3) full-scale cured plug tests, (4) shear bond tests, and (5) gravel pack penetration tests.
This paper presents results from the test program and provides data on commonly used dump bailer practices and equipment. Recommendations are made for placing cement and resin plugs utilizing dump bailers. This information should be useful to operators in planning and completing successful thru-tubing plugbacks.
Conversion of Drilling Fluids to Cements With Blast Furnace Slag: Performance Properties and Applications for Well Cementing
Authors: Cowan K. M. , Hale A. H. , Nahm J. J. 
Published: December 2007

ABSTRACT
A new method of obtaining unproved zonal isolation using drilling fluid solidification technology has been developed. A water-base drilling fluid is converted into a cement using a hydraulic blast furnace slag. Hydraulic blast furnace slag is a unique material which has low impact on rheological and fluid loss properties of drilling fluids, can be activated to set in drilling fluids which are difficult to convert to cements with other solidification technologies, is a more uniform and consistent quality product than Portland well cements, and is available in large quantity from multiple sources.
Because of its low impact on drilling fluid properties, blast furnace slag may be added to a drilling fluid at low concentrations during drilling operations. The Alter cake and drilling fluid in washed out sections thereby contain a hydraulic material. After reaching casing point, a mixture of drilling fluid containing chemical activators and higher concentrations of slag may be used to cement the casing string. Chemical activators from this mixture cause the slag in the filter cake and any bypassed drilling fluid to set. The result is a more complete seal for the annulus.
Fluid and hardened solid properties of blast furnace slag and drilling fluid mixtures used for cementing operations are comparable to properties of conventional Portland cement compositions. The design, testing and field application for this technology are similar to conventional cementing methods. Fluids with densities between about 1198 kg/m3 (10 lb/gal) and 2397 kg/m3 (20 lb/gal) may be prepared. The mixtures have been applied in wells where temperatures range from about 4°C (40°F) to 315°C (600°F).
This new solidification method provides the proper combination of fluid and solid properties, simplicity of design and application, improved zonal isolation, and broad applicability to bring drilling fluid solidification technology into widespread use.
Quantifying Common Drilling Problems With Mechanical Specific Energy and a Bit-Specific Coefficient of Sliding Friction
Authors: Pessier R. C. , Fear M. J. 
Published: December 2007

ABSTRACTThe conventional way to assess drilling performance in the oil field is to compare actual performance to statistical standards derived from offset records. By their nature, these standards are subjective and variable. While they are ideal to monitor short-range performance and trends in well- known, older fields, they lack the power of physical models to establish absolute, technical performance standards. Several authors have proposed models in which the drilling process is treated as a mechanical, energy-balanced system. Mechanical specific energy input, drilling efficiency, and a minimum specific energy equal to the rock strength are the three key elements of these systems.Full-scale simulator tests were conducted under controlled laboratory conditions to develop and validate an energy- balanced model for drilling under hydrostatic pressure. In these tests, wide variations in drilling efficiency from a few percent to three and four times were observed in the spectrum of common drilling practices. They provided new insights into the drilling process and the nature of common drilling problems.Analysis of field data revealed good correlation between simulator and field results. Using mechanical efficiency, specific energy input, and a bit-specific coefficient of sliding friction as key indexes of drilling performance makes bit selection and the diagnosis of failures and drilling practices more accurate and less ambiguous.
Effect of Wear and Bending on Casing Collapse Strength
Authors: Kuriyama Yukihisa , Tsukano Yasushi , Mimaki Toshitaro , Yonezawa Tetsuo 
Published: December 2007

ABSTRACT
In high-angle and horizontal wells, casing is subjected to severe wear and bending. Effect of wear and bending on the collapse strength was investigated by experiments and was evaluated using analytical approach as well as FEM. Empirical formulas allowing imperfections based on elastic collapse and yield onset pressure are derived.