bluuebunny/crossref_metadata_2025_split huggingface dataset:
Interpretation of Injection Well Pressure Transient Data in Thermal Oil Recovery
Authors: Satman Abdurrahman , Eggenschwiler Mauricio , Ramey Henry J. 
Published: December 2007

ABSTRACT
A study was made of methods for burned volume, or steam swept volume, determination from pressure transient test data taken on injection wells. The basis for determination of the swept volume was a new pressure transient model of a composite reservoir. The swept volume was modeled as a radial region adjacent to the injection well, which was considered to have both wellbore storage and a skin effect. The permeability, porosity, and compressibility of the reservoir fluid were considered to be different in the inner region, representing the swept region, and the outer region, representing the bulk of the reservoir. The fluid flowing was considered to be of slight compressibility. The solution technique was analytical, using the Laplace transformation with numerical inversion. This solution has a wide application for problems other than detection of swept volume in thermal oil recovery. Superposition was used to generate the effect of a pressure injectivity test after growth of a swept volume. The results indicate a short duration wellbore storage effect, followed by a semilog straight line whose slope is related to the permeability/thickness of the swept volume. The semilog straight line is then followed by a pseudosteady Cartesian straight line characteristic of the swept volume. Finally, a second semilog straight line appears, characteristic of the permeability-thickness of the unswept region. The discovery of the pseudosteady portion seems to be a major finding. It is possible that this method can be used successfully to detect the swept volume connected with injection wells.
Another important finding is that the initial wellbore storage effect dies in a few minutes, and the semilog straight line characteristic of the swept volume occurs almost immediately on shut-in. Further, the pseudosteady period occurs in durations from a fraction of an hour to a few hours. The consequences of this kind of test in thermal recovery operations appear to be extremely important. Early detection of swept volume would mean rapid measurement of the fuel concentration for a combustion operation, and the heat loss from a steam zone! There has not yet been time to study all consequences of this new interpretation method, but it is fair to say that this kind of well testing offers operational information of the greatest importance.
The Coalbed Methane Resource of the Illinois Basin
Authors: Archer Paul L. , Carr Donald D. , Harper Denver 
Published: December 2007

Abstract
A program was initiated to determine the extent of the coalbed methane resource and the location of the most favorable resource areas within the Illinois basin, and to obtain a better understanding of the relationships between selected variables and the gas content of coals. Preliminary gas in-place resource estimates are made based on coal desorption data and the most favorable resource areas are outlined. Limited and/or poor data precluded establishing relationships between various geological-chemical/physical parameters and coal gas content. Further investigations are required to determine such relationships and to define what percentage of this resource is producible.
Developments in Well Completion Techniques
Authors: Coburn R.W. 
Published: December 2007

Abstract
Field experiments indicate that well stimulation efficiency can be increased by engineering the completion process as an interrelated series of steps. These steps can be selected in a manner tat will create conditions most conducive to successful stimulation. Revision of perforating procedure, and consideration of injection rate per hole as a basis for designing fracture treatments will aid in successfully completing wells at lower cost. Pressure behavior patterns can be translated into efficiency which in turn can be indicative of the effectiveness of the treatment.

Introduction
The method of treating wells to increase production has not changed greatly through the years. Acid, and most recently, fracture fluid, have been injected into the formation with no real attempt being made to engineer the treatment. Injection rates, volumes, and perforating procedures have been selected on past experience or "rule of thumb" type thinking. In an attempt to improve the effectiveness of well stimulation methods, several innovations have been employed. Perforating procedure has been revised to reduce the number of holes shot. This is accomplished by reducing perforation density (no. of holes/ft) and by being increasingly selective in the placement of the perforations. The use of a value called injection rate/hole as a primary factor in designing stimulation treatments has increased the effectiveness of these treatments. The analysis of pressure behavior during a treatment has revealed a method of recognizing the occurrence of communication behind the pipe. This in turn led to the development of a means of predicting the effectiveness of a treatment. This paper is concerned with the completion of wells which require stimulation to increase production. The methods described herein can be applied to any treatment which depends upon the injection of fluid into the formation.

Developments
There are three basic phases of well stimulation which have been revised as a result of successful field experiments. They are: hydraulic fracturing methods, perforating procedure, and the evaluation of the completion procedure. Taken individually, each is important; together, they represent a method of increasing the efficiency of present well completion techniques.

Fracturing
Since the inception of hydraulic fracturing as a means of increasing oil production, the oil industry has been constantly seeking to improve the techniques. The volume of treating fluids has risen, injection rates have climbed steadily upward, and blocking agents have been developed. The treatments were designed principally by rule of thumb or by past experience.
IN Situ Evaluation of Several Tailored-Pulse Well-Shooting Concepts
Authors: Schmidt Richard A. , Warpinski Norman R. , Cooper Paul W. 
Published: December 2007

Abstract
Dynamic stimulation techniques that produce multiple fracturing in a wellbore are being investigated for enhanced gas recovery. Multiple fracturing appears to be especially promising for stimulating naturally-fractured reservoirs, such as the Devonian shales, since this may be the most effective technique for connecting a wellbore to a pre-existing fracture network. Previous studies have demonstrated that detrimental effects can occur with high-strength explosive techniques and that these effects can be avoided through the use of propellants.1,2 The use of propellants and other so-called tailored-pulse techniques depend on a controlled pressure-time behavior to minimize wellbore damage and maximize fracture growth by gas penetration.
This paper describes a series of five full-scale tests performed to evaluate various multi-frac concepts. The tests were conducted at the Nevada Test Site in cased, horizontal boreholes drilled in ash-fall tuff from a tunnel under 430 m of overburden. This site provides both realistic in situ conditions for the tests and access to the stimulated regions by mineback which permits direct observation of results. The five tailored-pulse concepts tested involve:
Case A - a decoupled explosive,3 Case B - a decoupled explosive with propellant booster,3 Case C - a small-diameter propellant charge with pressurized water pad,4 Case D - three successive shots of Case C, and Case E - a full-diameter charge of a progressively-burning propellant.2
While direct observation by mineback is highly beneficial, evaluation and analysis of these test results also depended heavily on other diagnostics. Thirty-six stress-meters and accelerometers were fielded in the surrounding rock to record the dynamic disturbances, and each borehole contained transducers to measure the actual cavity pressures. Pre-test and post-test evaluations include TV log, caliper log, and permeability measurements. Permeability, which evaluates the effectiveness of the created fracture network to transmit fluids, was determined by analysis of constant-pressure, water-injection tests and the subsequent pressure decline after shut-in.
Results show a large increase in formation permeability for Case E, modest increases for Cases B, C, and D and a decrease for Case A that appears due to the formation of a stress cage. A comparison of Case E results with previous tests suggests a multiple fracture criterion based on pressure rate with little effect of peak pressures.
Empirical Evaluation of Clinton Sand Well Performance
Authors: Skillern Charles R. 
Published: December 2007

Abstract
The production economics of tight to near-tight formations such as the Clinton sands of Ohio have become increasingly marginal due to rapidly increasing well costs and geologically less favorable areas to drill. To evaluate the potential for improved well performance, the Gas Research Institute (GRI) sponsored the empirical investigation of historical Clinton sand well performance presented herein.
The study is based on well data from 303 wells in northeastern Ohio which were drilled between 1963 and 1974. All the wells were single-completions stimulated by hydraulic fracturing for which at least five years of uninterrupted production data are available. The data are believed to be representative of Clinton wells in the 1963 to 1974 time frame and were selected only on account of availability. Statistical regression methods were used to determine well parameters which impact individual well performance. The five-year cumulative production (first five years) for each of the 303 wells was used as the dependent variable in a multivariable linear regression equation, with the statistically significant well parameters as independent variables.
The empirical regression equation was used to estimate average well performance (five-year cumulative production) for geographically oriented subsets of the 303-well data base with varied levels of stimulation treatment volume. Significant variations in well performance are demonstrated as a function of apparent geologic variations and variations in stimulation treatment volume. Historical production (303 wells) could have been increased by 15 percent through use of near-optimum stimulation treatment volumes. A method is proposed which utilizes the statistical regression methods of the study, in conjunction with exploratory drilling in areas which are geologically similar to those represented by the data base, to assist in optimizing future Clinton sand production.
Development of Associative Polymer Technology for Acid Diversion in Sandstone and Carbonate Lithology
Authors: Eoff Larry , Dalrymple Dwyann , Reddy B. R. 
Published: December 2007

AbstractThis paper describes the use of associative polymer technology (APT) to achieve fluid diversion during an acid stimulation treatment. APT involves the use of a very low-viscosity aqueous polymer solution. It reacts immediately with the formation surface to significantly reduce the ability of subsequent aqueous fluids to flow into high-permeability portions of the rock. The first stage containing the APT predominately will enter the most permeable area, diverting following acid stage(s) to less permeable sections of the rock. APT has little or no effect on the flow of subsequent hydrocarbon production. Furthermore, in rock containing significant proportions of sandstone-type lithology, the water permeability of the treated zone is decreased permanently, resulting in post-treatment reduced water production from the treated zone.This paper includes a general description of associating polymers and their properties, as well as a detailed description of the laboratory development of the current system. Laboratory data showing the ability of APT to reduce the ability of aqueous fluids to flow through porous media is presented. Parallel flow studies using water-saturated and oil-saturated cores are presented that show the ability of APT to divert acid in both sandstone and carbonate cores. These tests also show the ability of APT to decrease water permeability in the water-saturated core while the diverted acid increases the permeability of the oil-saturated core.
An Evaluation of the Geopressured Energy Resource of Louisiana and Texas
Authors: Samuels Garland 
Published: December 2007

Abstract
The economics of extracting either the geothermal energy or natural gas from geopressured aquifers does not look promising. The combined requirements of high well flow rates, long life, and the necessity for close well spacing to minimize the cost of the collection system may be incompatible with the actual characteristics of the reservoirs. These factors place such stringent requirements on the reservoir size, permeability and compressibility that the number of promising production areas may be severely limited.
Natural Gas from Tight Siltstones in the Catskill Clastic Wedge in West Virginia
Authors: Schwietering Joseph F. 
Published: December 2007

Abstract
Stratigraphic studies of Middle and Upper Devonian rocks in West Virginia suggest that thick zones of interbedded siltstone and shale present between the Devonian Shale gas fields in southwestern West Virginia, and the gas fields in Upper Devonian sandstones and siltstones in central and eastern West Virginia may contain important reserves of natural gas. Wells drilled into these zones of interbedded siltstone and shale should be completed in the same way as wells drilled into the black shales; i.e., the entire zone should be fractured, not selected siltstones.
Foam Fracturing: Theories, Procedures and Results
Authors: Gaydos J. S. , Harris P. C. 
Published: December 2007

ABSTRACT
For the past several years, foam has been used in many treatments as a fracturing fluid. Although many different types of reservoirs have been stimulated with foam, the primary zones of interest in Eastern Kentucky and Southern West Virginia have been the Berea Sandstone and the Devonian Shales. Due to the nature of these formations, i.e. low permeability, low bottom-hole pressure and water sensitivity, foam fracturing has been a successful technique.
This paper presents the basic background theory of foam and presents several basic treatment designs which have been used successfully in the Devonian Shales and Berea Sandstone. Production histories for up to two years on a number of wells fractured with foam are compared to production histories of offset wells which were conventionally fractured with gelled water. In all the side-by-side comparisons, foam fracturing was found to give production results either as good as, or better than, conventional fracturing with gelled water.
Methane Recovery from Deep Unmineable Coal Seams
Authors: Allred Larry D. , Coates Ralph L. 
Published: December 2007

ABSTRACT
Mountain Fuel Supply Company and the U. S. Department of Energy are conducting a joint project to demonstrate production and recovery of methane gas from deep coal seams in the Book Cliffs coal field of central Utah. The objective is to drill three wells to depths near 3000 feet to determine if commercial quantities of gas can be produced, and then to install production facilities for injecting the gas into the Mountain Fuel Supply gas transmission system.
Two of the three wells have been drilled and testing has been initiated. Five coal seams were encountered at depths between 2681 and 3112 feet. Core samples were obtained and desorption measurements indicate gas contents up to 400 cu ft/ton. The gas is approximately 95 percent methane. Water influx tests were made and water pumping equipment is being installed. Plans are being formulated to hydraulically stimulate the principal coal seams with nitrogen foam to increase production.
Methane Drainage from the Mary Lee Coalbed, Alabama, Using Horizontal Drilling Techniques
Authors: Perry John H. , Prosser Leonard J. , Cervik Joseph 
Published: December 2007

ABSTRACT
The Bureau of Mines has developed several techniques for draining methane from coalbeds in advance of mining. Drilling long horizontal holes from an underground location is one of these techniques which has been successfully demonstrated in the Pittsburgh and Sunnyside coalbeds. A similar project was successfully conducted in the Mary Lee coalbed at Jim Walter Resources Inc., No. 4 mine. In a year about 1.13 million m3 (40 MMcf) of methane was recovered from the coalbed.
Water Injection Completion Philosophy in A Deepwater Subsea Environment Requiring Sand Control: A Case Study of 29 Injection Wells West Of Shetland.
Authors: Roy Alistair , Thrasher David , Twynam Allan , Wilson Allan 
Published: December 2007

Abstract
Water Injection completion selection in a deepwater subsea environment requiring sand control is currently an inexact science with lack of a proven track record for life of field solutions. The West of Shetlands (WoS) fields Foinaven, Schiehallion and Loyal have been on injection since 1997 and are starting to develop a substantial track record of injection performance. This case study will provide a performance comparison of the 2 main completion types installed to date, namely Cased and Perforated (C&P) and standalone Wire Wrap Screens (WWS), along with a subset of a three zone Smart well completed with premium sand screens. The comparison focuses on 4 main areas;
– Well Longevity – Completion Efficiency (skin) – Injection Conformance (Near Wellbore) – Performance of single and multi-zone injectors
The WWS screen performance is further subdivided by clean-up technique of which there are currently 5;
– Backflow Oil Based Mud (OBM) – Bullhead Oil Based Mud – Bullhead Water Based Mud after spotting Breaker – Toe Fracture using External Casing Packer – Displace OBM to Solids Free OBM and bullhead
A variety of data will be presented as part of the comparison including, PLT Data, MDT Data, PFO Results, Hall Plots, UCS Data. A simple set of criteria is presented to select when C&P or sand screens are viable completion solutions.
Production Strategy for Thin-Oil Columns in Saturated Reservoirs
Authors: Kabir C. S. , Agamini M. , Holguin R. A. 
Published: December 2007

AbstractMaximizing oil recovery in thin and ultra-thin (&lt; 30 ft) oil columns is a challenge because of coning or cresting of unwanted fluids, regardless of well orientation. Significant oil is left behind above the well completion even for horizontal wells when bottom-or edge-water invasion occurs.Two depletion strategies may be enacted to improve recovery of the remaining oil. In the first option, a conventional horizontal is completed below the gas/oil contact (GOC). Once the well waters out, the well is recompleted in the gas zone. Completion occurs either at the crest for a small gas-cap reservoir or at the GOC, inducing reverse cone, for reservoirs with thick-gas columns. Alternatively, one can skip the initial oil completion. Gravity-stable flooding is required to maximize reserves.Extensive flow simulations in multiple, history-matched models have shown that the proposed strategy improves recovery significantly. Two field examples are presented to demonstrate the usefulness of the proposed method.Using multivariate regression, simple correlations were developed for quick screening of the proposed approach. Experimental design formed the backbone of a parametric study involving various reservoir, fluid, and process variables. We tested and validated the correlations with independent sets of experimental and published field data.
Log Reprocessing: Petrophysical Lessons from the Giant Oil and Gas Fields of Saudi Arabia
Authors: Kersey David G. , Al-Ali Hussein A. , Eyvazzadeh Ramsin Y. , Phillips Craig , Tjan Tjwan L. 
Published: December 2007

Abstract
Results from Saudi Aramco's log reprocessing project provide guidelines for reprocessing fields of all sizes. The database included openhole logs from 8,700 wells acquired over almost seventy years by three contractors using various generations of tools. The main goal was to develop a functional, accurate and accessible log data base of both quality-controlled raw logs and uniformly processed, core-calibrated interpretation logs. The project was divided into five phases: log editing, core/log integration, normalization, petrophysical processing and archiving.
Analysis of an Annular Pressure Buildup Failure during Drill Ahead
Authors: Pattillo P. D. , Cocales B. W. , Morey S. C. 
Published: December 2007

Abstract
While drilling ahead in salt on the Pompano A-31 (Gulf of Mexico) wellbore below the 16 in. shoe, the rotary stalled abruptly and the drill pipe simultaneously became stuck. Subsequent calipers indicated the 16 in. casing to be deformed onto the drill pipe at approximately 250 ft.
To the authors' knowledge, this represents the first instance of an annular pressure buildup (APB) failure during drilling. APB is typically associated with extremes of temperature change resulting from production operations. In the current instance, the temperature change was solely from circulating drilling fluid.
The manuscript provides a detailed post-analysis of the 16 in. casing failure:
An overview of the conventional casing design for this well, indicating that normal operating conditions should not have resulted in a failure; A review of the failure event, substantiated by field measurement and photographs; An investigation of APB associated with inadvertently closing the 16 in. casing annulus at the surface, demonstrating the magnitude of thermally induced pressure load that can result; Consideration of an alternate failure mode, column buckling, to demonstrate that this failure mode was not active in this wellbore; A finite element model of the drill pipe/16 in. casing/20 in. casing trio indicating that, in addition to collapse of the 16 in. casing and subsequent sticking of the drill string, the outer 20 in. casing was also damaged by the event.
The latter item is particularly important in that damage to outer strings can be easily overlooked as one concentrates on the collapsed casing and drill pipe fish. Damage to the outer 20 in. string is confirmed by a mechanical caliper.
Conclusions in the paper center on confirmation of the postulated failure mode by field measurement and recommendations for avoiding such an event.
Using Multifrequency Sonic Velocities for Geomechanics Applications
Authors: Lacy Lewis L. , Jiao Di 
Published: December 2007

Abstract
A relatively new method has been developed and tested to determine compressional and shear wave velocities and quality factors versus frequency for reservoir rock under a wide variety of reservoir conditions. This new method depends on measuring the Dynamic Elastic Moduli (DEM) at multi-frequencies. The reasons for performing multi-frequency measurements are reviewed in the paper along with potential reservoir applications used in petroleum engineering, geophysics and dipole sonic log calibrations. Typical data are reviewed using pure aluminum for calibration and investigating the method using both Berea sandstone and reservoir sandstone at different saturation conditions.