bluuebunny/crossref_metadata_2025_split huggingface dataset:
Field Examples Of Barrier Detection With Unsteady-State Techniques
Authors: Schrenkel Jack 
Published: December 2007

PUBLICATION RIGHTS RESERVED
This paper is to be presented at the 36th Annual Fall Meeting of the Society of Petroleum Engineers of AIME in Dallas October 8–11, 1961, and is considered the property of the Society of Petroleum Engineers. Permission to publish is hereby restricted to an abstract of not more than 300 words, with no illustrations, unless the paper is specifically released to the press by the Editor of JOURNAL OF PETROLEUM TECHNOLOGY or the Executive Secretary. Such abstract should contain conspicuous acknowledgment of where and by whom the paper is presented. Publication elsewhere after publication in JOURNAL OF PETROLEUM TECHNOLOGY or SOCIETY OF PETROLEUM ENGINEERS JOURNAL is granted on request, providing proper credit is given that publication and the original presentation of the paper.
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 considered for publication in one of the two SPE magazines with the paper.

Abstract
Two field case histories involving three wells are presented, showing the effect of faulting on the pressure buildup and pressure drawdown characteristics. Example 1 has several unfavorable conditions existing - yet it shows there is a barrier present. Example 2 has two wells with drawdown curves measuring the distance to the major fault with good precision.
It is concluded that barrier detection methods, using the unsteady-state techniques, are a useful exploration tool.

Introduction
The theory of barrier detection was published by Horner in 1951. In his paper, Horner showed how formation capacity could be obtained, what the effect of boundary conditions would have on the final static pressure, and how distances to barriers could be computed from anomalous buildup tests. Since the publication of Horner's paper, Dolan and Coauthors, and Jones have presented the results of pressure buildup and pressure drawdown tests that were near faults or other barriers.
Presented here is an example which confirms the existance of a known fault and a second example which predicted the distance to a fault, which subsequent drilling proved to be correct.

THE THEORY OF BARRIER DETECTION
Horner developed his theory of barrier detection by the superposition of the solution of two equations. One of the equations was for the well and the other for the image well located across the barrier. The barrier is normal to the line of sight from the well to the phantom well.
New Analysis Technology for Determining Fracture Parameters from Calibration Treatments: Case Histories, Rocky Mountain Area
Authors: Warembourg P. A. 
Published: December 2007

ABSTRACT
In May 1987, an innovative technique was presented to the industry by J. L. Castillo that introduced a new plot for fracture pressure decline analysis ("Modified Fracture Pressure Decline Analysis Including Pressure-Dependent Leakoff" (SPE 16417)).1 The plot is used to determine the pressure parameters (PC, P*) required in the Nolte leakoff calculations. The plot also set the stage for an analysis technique that enhances the square root of time plot to determine closure, and the Nolte type curves to determine P*.
Case histories demonstrate how the analysis technique is applied. The technique uses a combined analysis and simulator program to determine P*, total leakoff coefficient, closure pressure and closure time. These parameters are determined from a single calibration treatment. Advantages of the technique include speed and simple operation. An estimation of fracture height created during the calibration treatment is also made. Fracture height is a critical parameter that is not always available unless reliable surveys are performed after a calibration treatment. This is not to imply that surveys can now be eliminated. Surveys should always be run whenever possible to confirm height. There will invariably be discrepancies in determining fracture height, because surveys show the best case (inclined vs true vertical fractures), and calculated heights using three-dimensional (3D) simulators require more data than are usually available.
The case histories show the comparison between the heights determined by the analysis and the heights determined by surveys. The other calculated parameters are given for several formations and locations. The importance of the input and output parameters used in the case histories is discussed. Fracture height and total system leakoff are two critical variables needed for efficient fracture design. The method to obtain these variables and their value is presented.
Field Cement Sampling and Testing: A Case Study in the Madden Deep Unit, Wyoming
Authors: Reeves N. K. 
Published: December 2007

ABSTRACT
Drilling and cementing in the Madden Deep Unit of west central Wyoming is characterized by formation pressure variances, gas influx and lost circulation problems. These problems must be considered when designing cement slurries for each casing and liner job. Consideration must also be given to the fact that large volumes of cement are required for these jobs.
To maximize the success of each cement job, extensive laboratory pre-testing and field blend testing are conducted prior to moving cement to location. This procedure consists of designing and testing a cement slurry to meet such parameters as thickening time, fluid loss control, compressive strength development and hydrostatic pressures. This pre-testing is followed by testing each load of field cement blend to detect any deviations from the pilot cement.
This paper will discuss such aspects of the field blend testing as bulk plant sampling, acceptable thickening time windows, test repeatability, and the use of dry additive identification. A major point will show how the use of dry additive identification is a very valuable and time saving tool in the testing of field blends.
Water Resistivity from Spontaneous Potential Logs in the Minnelusa Formation, Powder River Basin, Wyoming
Authors: Policky B. R. , Iverson W. P. 
Published: December 2007

ABSTRACT
Water resistivity (Rw) values computed from the spontaneous potential (SP) log frequently yield low values for the Minnelusa formation of the Powder River Basin, Wyoming when compared with Rw values determined directly from water samples. These anomalies arise when conventional SP analysis techniques for obtaining Rw are fallowed. Therefore, a new technique for determining the SSP deflection and a new equation which salves for Rw have been developed.1
To construct and validate the new technique and equation, a complete appraisal of the current methods of obtaining estimates for water resistivity has been provided. A substantial number of wells, which produced 100% water upon testing and span a large cross-sectional area of the basin, were analyzed. In addition, oil producing wells have been included to verify Rw estimates for intervals bearing hydrocarbons.
Using this new procedure has resulted in significant improvements in the accurate evaluation of the hydrocarbon potential of a prospective interval within this formation.
Multiple Hydraulic Fracture Propagation in Oil Sands
Authors: Chhina H. S. , Best D. A. , MacKenzie W. T. 
Published: December 2007

ABSTRACT
A multiple hydraulic fracture field test was conducted in the McMurray formation of the Athabasca oil sands in Alberta, at a depth of 235 mKB. Due to the low fluid injectivity into the formation, hydraulic fracturing preceding hot water and/or steam injection was considered a viable means of establishing interwell communication. In situ stress tests conducted at the wells indicated the minimum principal stress to be in the vertical direction. This meant horizontal fracturing was feasible at 235 mKB. Subsequently two fracture treatments were conducted, a mini-fracture test followed by the main propped fracture. The fracture monitoring methods used were as follows:
Tiltmeters Temperature observation well Radioactive proppant Fracture extension pressures Post fracture log evaluation wells
Tiltmeter and observation well data indicated horizontal fracturing during the mini-fracture test. The subsequent main fracture treatment showed similar results during the initial injection stage, however evidence of vertical fracturing was prevalent during the proppant injection stage. Numerical modelling conducted at a later date, using a finite element stress-strain model, indicated that in a near isotropic stress environment there existed a critical maximum formation strain, beyond which the minimum principal stress direction can change. As a result of the above work, the fracture design parameters for oil sands, such as injection rates and fracture fluid viscosities can be adjusted to minimize vertical fracturing at shallow depths, where initially horizontal fractures are favoured.
Diesel-Based Gel Concentrate Improves Rocky Mountain Region Fracture Treatments
Authors: Yeager R. R. , Bailey D. E. 
Published: December 2007

ABSTRACT
More than 500 oil and gas wells in the Denver-Julesburg (D-J) Basin have been successfully stimulated using a water-base fracturing fluid, gelled with a diesel-base gel concentrate. Since the use of this system began in 1985, six different D-J Basin formations, with bottom hole temperatures ranging from 120°F to 260°F, have been treated. Ammonium chloride and potassium chloride have both been used with the continuously mixed gel to help protect clays.
This paper presents a brief description of the chemistry of the system, however, the main emphasis of the paper is toward operational considerations and economics of using diesel-based gel concentrate. The considerations include continuous (on-the-fly) mixing of the gel and an evaluation of ammonium chloride versus potassium chloride for clay protection.
A Summary of the Big Muddy Field Low-Tension Flood Demonstration Project
Authors: Borah M. T. , Gregory M. D. 
Published: December 2007

ABSTRACT
A 90-acre demonstration of the low-tension flood process was recently completed in the Second Wall Creek reservoir of Wyoming's Big Muddy Field. This paper addresses the overall performance of the project, including a comparison to the laboratory design. It also discusses some of the practical aspects of a low-tension flood.
Early Kick Detection Holds Kill Pressure Lower
Authors: Griffin Phil 
Published: December 2007

This paper was prepared for the SPE Symposium on Mechanical Engineering Aspects of Drilling and Production to be held in Fort Worth, Tex., March 5–7, 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 requested 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 discussions may be presented at the above meeting and, with the paper, may be considered for publication in one of the two SPE magazines.

Abstract
Within the last year the oil industry has undergone a tremendous self-training program with respect to the application of engineering theories to the control of threatened blowouts. This education program has considered both highly technical and comp] i ca ted systems for use by drilling engineers and has also considered highly simplified systems for use by rig floor personnel and other non-engineer supervisory personnel. This paper restresses the need for the continuance of this educational program and points out primarily for rig and non-engineering personnel the necessity of detecting a kick as early in its life as possible. Surface indications that a kick is in progress are discussed. Kick detection instrumentation is also discussed. Examples are shown whereby early kick detection can hold pressures required to bring the well back under control within both surface and downhole pressure limits.
Within the last year the oil industry has undertaken a self-training program with respect to the application of engineering theories to help control threatened blowouts, This education program has considered both highly technical and complicated systems for use by drilling engineers and has also considered highly simplified systems for use by rig floor personnel and other non-engineer supervisory personnel.
The theories of Gulf Oil Company's Goins and O'Brien have been studied, modified, expanded, condensed, subjected to computers, and field tested and generally have become widely accepted by the industry. The whole key to the Goins-O'Brien approach is the establishment and maintenance of a constant and sufficient pressure in the annulus opposite a producing formation.
Goins and O'Brien have shown that the drill pipe-well bore combine to behave similar to a simple "U" tube (figure 1) and being such react to a downhole situation as a "U" tube would be expected to react to a similar situation. Further investigation of "U" tube theory shows that the pressure at the "top of the tubes" can be used to determine the pressure at the bottom of the "U".
Development and Application of New Type Curves for Pressure Transient Analysis
Authors: Yeh N-S. , Agarwal R. G. 
Published: December 2007

ABSTRACT
Use of type curves based on the dimensionless pressure and its logarithmic derivative has become a standard method for analyzing well tests data. Recently, a new procedure for constructing type curves using a dimensionless pressure group which involves the ratio of the dimensionless pressure and its derivative was developed and reported in the literature. This paper extends the preceding concept not only to the pressure variable but also to the time variable. That is a new dimensionless time group is introduced for type curve construction. The major advantage of this is that the matching procedure requires the movement of the field data only in the horizontal direction. This improvement not only facilitates the type curves match but also increases the reliability of the analysis results.
New type curves are presented for wells in radial systems with wellbore storage and skin, and vertically fractured wells with uniform-flux, infinite-conductivity and finite-conductivity fractures. Field examples are included to illustrate the utility of the new type curves and the analysis procedure. The possible application of this method to heterogeneous systems such as naturally reservoirs are also discussed.
Reservoir Descriptions Via Pulse Testing: A Technology Evaluation
Authors: Chopra A. K. 
Published: December 2007

ABSTRACT
Implementation of pulse testing technology as a tool to obtain reservoir descriptions has been limited to only certain types of reservoir heterogeneities. An integrated approach to evaluate pulse testing as a means of obtaining reservoir descriptions for multilayer heterogeneous reservoirs is presented in this paper. A method is developed to simulate pulse tests using a gridded model. Pulse test responses in multilayer heterogeneous reservoirs are investigated for unequal layer pressures, vertical layer heterogeneities, and wellbore storage effects both at the active and observation wells.
The integrated approach is applied to a pulse test pilot completed in a San Andres reservoir. The usefulness of pulse testing is found to be highly reservoir specific. Pulse test data alone are not sufficient to derive reservoir descriptions for multilayer heterogeneous reservoirs and must be used in conjunction with geological, petrophysical, and single well pressure transient data. Pulse testing may not provide an adequate definition of vertical layer heterogeneities for tertiary miscible gas performance predictions and can be used only to refine the definition of high speed layers which control gas cycling in a tertiary miscible gas process. The pulse test derived reservoir description may be adequate for waterflooding predictions under certain situations. For primary depletion predictions, single well pressure transient data are sufficient when coupled with geological and petrophysical data. The integrated approach to evaluate pulse testing is recommended before actually conducting pulse tests in the field.
Comparative Rheology of Water-Based Drilling Fluids With Various Clays
Authors: Güven N. , Panfil D. J. , Carney L. L. 
Published: December 2007

ABSTRACT
Water-based drilling fluids comprising different clays (bentonite, saponite, and sepiolite) have been autoclaved in the temperature range of 300–600°F (149–316°C) under appropriate confining pressures in order to simulate the conditions encountered while drilling deep oil and gas wells. The clay mineral saponite represents the magnesium analog of montmorillonite which is the aluminous clay mineral in bentonite. Both montmorillonite and saponite are characterized by a swelling silicate lattice and an excess layer charge. Morphologically, saponite and montmorillonite are similar and they consist of thin platelets and films mostly in the micron-size range. Sepiolites are similar in chemistry to saponites but they possess a fibrous morphology and a neutral lattice. These basic characteristics of the clays are found to lend different rheological and wall-building properties to the drilling fluids. Saponite fluids display much higher viscosities and significantly lower fluid losses at high temperatures. Saponite fluid was also more stable than bentonite fluid at high temperatures and in the presence of common Na, K, and Ca salts and hydroxides due to the nature of reactions between these compounds and bentonite. Mixing fibrous sepiolite with saponite enhances the viscosity of these fluids in the presence of common salts. At high temperatures sepiolite readily converts to a smectite and improves the fluid rheology and fluid losses.
Coiled Tubing in Horizontal Wells
Authors: Cooper R. E. 
Published: December 2007

ABSTRACT
Coiled tubing is an effective tool in logging and workover applications of horizontal wells. Several operators have taken advantage of using coiled tubing to log or perforate wells which could not have been performed with conventional wireline methods. Specialized surface and subsurface equipment has been developed to facilitate the use of wireline tools with coiled tubing.
Production logging data, particularly multiphase flow testing, in horizontal wells have proved difficult to interpret. The use of coiled tubing packers and flow diverters to help isolate flow rates has improved production profile data.
Coiled tubing has been used to selectively place stimulation fluids over long sections of horizontal hole, i.e., 1,200ft (366m) and greater. It has also been used in zone isolation, cement squeezing, and setting of bridge plugs. Several cases are presented where the use of coiled tubing eliminated or reduced conventional rig expense.
Performance of Vertical and Horizontal Wells in Reservoirs Containing Discontinuous Shales: Numerical Studies of Two North Sea Fields
Authors: Borner D. L. , Haldorsen H. H. , Harrison P. F. , Hopwood A. P. , MacDonald C. J. 
Published: December 2007

ABSTRACT
Many reservoirs contain a thin oil column with underlying water or with a gas cap present. To decide on the viability of such fields, detailed single-well simulation studies are often made to forecast oil, gas and water rates through time. This paper investigates the effects of discontinuous shales on the performance of vertical and horizontal wells in these reservoirs. Stochastic techniques are presented for representing shales on a simulation grid.
Conclusions are that it is necessary to include shales explicitly if the variability of behaviour in vertical wells is to be captured; that shales cutting the wellbore have the most significant effect on performance; and that small shales can be represented via an effective vertical permeability for horizontal well simulation.
Numerical Simulation of Gravity-Stable Hydrocarbon Solvent Flood, Wizard Lake D-3A Pool, Alberta, Canada
Authors: Hsu H. H. 
Published: December 2007

ABSTRACT
This paper presents a history match and prediction for the Wizard Lake D-3A pool reservoir in Alberta, Canada. The reservoir is a dolomitized bioherm reef with an initial oil pay zone of 648 feet (197.5 m) and it is underlain by the Cooking Lake aquifer. A fieldwide 3-D (11×14×53), 4-component (gas, solvent, oil, water) simulation model is used to history match the reservoir pressure, the oil, gas, and water productions, the gas/solvent, solvent/oil, and oil/water contact locations. This paper will address several features of the model which were developed specifically for this study. These include treatment of openhole completion and handling of solvent and water coning with the coarse grid model. It will also discuss different methods of calculating the fluid contact locations from simulation results.
The history match covers a time span of 3 6 years (1951–1986). The reservoir was initially under primary production for 19 years during which reservoir pressure dropped below the bubblepoint pressure and a secondary gas cap formed. Hydrocarbon solvent flooding started in late 1969 and continues to the present time. During the solvent flood, both residue gas and water were injected to raise the reservoir pressure back to its original value. At the completion of the history match, the model was used to make prediction runs to assist in planning the pool’s production and injection strategy.
Phase Equilibria for Enhanced Oil Recovery in an n-Butane Enriched Carbon Dioxide + Black Oil System
Authors: Chaback J. J. 
Published: December 2007

ABSTRACT
Discussed herein are three aspects of fluid phase equilibrium as they relate to enhanced oil recovery processes and to the simulation of such processes. First, experimental phase equilibria measurements show that the addition of n-butane can lower saturation pressures relative to those of base oil + CO2 mixtures. Enrichment of the injection gas with only 10 mol·% n-butane reduces the saturation pressure at the L-V critical point by 1400 psia [9.65 MPa] and by nearly 2250 psia [17.51 MPa] for a 20 mol·% addition. Likewise, addition of 6 mol·% n-butane reduces the slim tube minimum miscibility pressure by approximately 550 psia [3·79 MPa]. Thus, a n-butane enriched CO2 injection gas can achieve multiple contact miscible displacements in lower pressure reservoirs. It would not be possible to miscibly flood those low pressure reservoirs with pure CO2 injection.
Second, phase distribution curves from constant composition volumetric expansion experiments illustrate the solvent capacity of the injection gas for the base oil.
Third, a set of equation of state parameters describing the fluid PVT and phase behavior is presented and used to represent the suite of measured properties. To mimic miscibl·e-like behavior during multiple contacting, severe compromises are required in the representation of base oil and first contact base oil + injection gas mixture properties.