bluuebunny/crossref_metadata_2025_split huggingface dataset:
Steady-State Bitumen-Water Relative Permeability Measurements at Elevated Temperatures in Unconsolidated Porous Media
Authors: Bennion B. , Sarioglu Gurk , Chan M. Y. S. , Hirata Toshiyuki , Courtnage Dave , Wansleeben John 
Published: December 2007

Abstract
Accurate drainage and imbibition relative permeability data are essential for the accurate prediction of the performance of heavy oil reservoirs undergoing cyclic steam stimulation or steam drives. There is very little published data regarding steady state relative permeability measurements at elevated temperatures. This paper documents two complete water-bitumen steady state drainage and imbibition tests conducted at a temperature of 200° C at full reservoir pressure and overburden conditions utilizing composite core stacks of actual, preserved reservoir core material. The test results indicate substantial hysteresis effects in the non-wetting (bitumen) phase and provide insight into the wettability, displacement efficiency, residual saturations and endpoint permeabilities and relative permeabilities for an unconsolidated heavy oil sandstone reservoir.
East Flour Bluff (Deep) Cycling
Authors: Smith Louis E. , Page George O. , Snyder Louis J. 
Published: December 2007

Abstract
The East Flour Bluff (Deep) Field is composed of a series of abnormal pressure gas reservoirs. A production test of the J-55 zone indicated a condensate yield of more than 100 BPM. Laboratory analysis showed that the dew point pressure was near the 7800 psi reservoir pressure and indicated severe retrograde behavior. Initial production from the zone, which reduced the reservoir pressure to 6800 psi, confirmed the analysis as condensate recovery dropped to 80 BFM. An additional zone was tested and found to have initial condensate yield of 45 BPM. This paper describes how cycling operations were evaluated. Reservoir performance calculations were made for natural depletion and for several possible cycling cases using a compositional reservoir simulator. In these calculations the B-W-R equation of state was used to predict phase behavior. Economic analyses of these cases combined with anticipated deliverability requirements for depletion of area reserves under the existing gas sales contract resulted in selection of the optimum cycling plan. Of interest is the flexibility designed into the compressor installation which is capable of high pressure injection as well as low pressure sales compression without requiring recylindering.
Introduction
The East Flour Bluff (Deep) Field is composed of 13 abnormal pressure gas reservoirs. Production is from Marine Frio sandstones which Production is from Marine Frio sandstones which occur from 9,000 to 11,000 feet subsea. The field is located in the Laguna Madre waterway near Corpus Christi, Texas, as shown in Fig. 1. Gas from this field is committed for sale along with gas from the Flour Bluff, East Flour Bluff, and Pita Island Fields. All leases in the East Flour Bluff (Deep) Field are included in a single royalty unit. In mid-1968, the East Flour Bluff (Deep) J-55 reservoir was tested and found to have an original yield of 102 barrels of condensate per million standard cubic feet of gas produced. Laboratory analysis of a recombined gas sample showed a dew point close to the original reservoir pressure of 7800 psi and indicated severe retrograde behavior. Subsequent production from this reservoir indicated a dew production from this reservoir indicated a dew point of about 7500 psi; condensate yield has point of about 7500 psi; condensate yield has dropped to 80 BPM at a reservoir pressure of 6800 psi. The other major reservoir, the J-77, was tested and found to contain a 45 BPM gas condensate. From these results, it was apparent that gas cycling of these reservoirs should be evaluated in an attempt to maximize condensate recovery.
The Evidence for and Implications of a Fractal Distribution of Petroleum Reserves
Authors: Brett J. F. , Feldkamp L. D. 
Published: December 2007

ABSTRACT
This paper presents preliminary empirical and physical evidence that oil and gas field sizes are fractally distributed. Further, the paper shows that this evidence predicts a fractal dimension greater than 1.0, which implies that larger quantities of hydrocarbons exist in smaller fields than in larger fields. If this hypothesis is true more hydrocarbons remain undiscovered in smaller fields than have been discovered to date, even in mature areas. If the hypothesis is false, the outlook for mature areas in not nearly so optimistic.
The paper also presents a list of "key questions" that should be answered before one could be certain of a fractal distribution of reserves, and it gives a reliable estimate of the distribution's dimension.
Estimating Oil Reserve Variability by Combining Geologic and Engineering Parameters
Authors: Holtz M. H. 
Published: December 2007

ABSTRACT
Uncertainty in oil reserve analysis results from both sources of error in an analysis and the affects of changing production technology. This uncertainty can be constrained by analyzing reserves within the context of a geologic play. The geologic plays are based on categorization of geologic heterogeneity, which corresponds to engineering parameters.
Monte Carlo simulation can be used to combine the effects of both error in reserve analysis and the affects of changing production technology. When this approach is used within a geologic play framework, the resulting reserve probability distributions can accommodate geologic uncertainty and quantify reserve variability potential (RVP). Calculating the RVP of a individual reservoir is a three step process. First the OOIP/acre values for a given play are fit to a general probability distribution function. Second, play probability distribution functions are fit for reservoir recovery efficiencies at various stages of reservoir development Finally, the delerministically calculated average OOIP/acre for individual reservoirs is applied with the play volumetric and recovery probability distributions, to generate RVP distributions. The 50th percentile reserve value and the 10-90 percentile range is the RPV, and this describes the reserve uncertainly.
This method allows more accurate reserve estimates and bridges the gap between advocates of deterministic versus probabilistic reserve estimation. Geologic assurance is built into the RVP, and engineers are thus better able to assess risk in reserve calculations. Applying the concept of RVP also eliminates the need to categorize reserves as proved, probable, and possible by modeling reserves as a continuum.
A Consistent Probabilistic Approach to Reserves Estimates
Authors: Capen E. C. 
Published: December 2007

Abstract
This paper breaks no new ground in it's call for using practical probabilistic methods for defining reserves. In fact the problem has always begged for a probabilistic solution. The bigger surprise is that an industry which prides itself on its use of science, technology, and frontier risk assessment methodologies finds itself in the 1990's with a reserves definition more reminiscent of the 1890's. The petroleum industry uncovers uncertainty at virtually every stage. Its definitions need to reflect that fact. I hope this paper provides a provocation or two for future debate on this important topic.
When presenting some of these ideas during a panel discussion at the SPE 1991 Annual Technical Meeting, I half jokingly remarked that had the Society been charged with describing the probability of a fair coin, it could not have agreed on a method of quantification: The Society suggests the following guidelines. Heads: A likely event or an event that certainly may occur. Tails: An entirely possible event or a probable event. Having to attach actual numbers to heads or tails would prove confusing to the membership and will add nothing of value.
Effective Environmental Management
Authors: Frederick J. D. 
Published: December 2007

ABSTRACT
The emergence of the new environmentalism and the resultant wave of regulation forces industry to rethink how it deals with related environmental issues.
How does business account for environmental programs to ensure that society is apprised early enough to avoid catastrophic and costly over-regulation? How does business streamline to reduce environmentally related costs while maintaining the high quality of its product or service?
Information that is publicly released concerning environmental issues must be properly managed to guard against misuse.
Consultants can be a cost-effective tool when properly managed and when utilized as a supplement to in-house staff.
Industry must look upon agency staff as partners in achieving a common societal goal, rather than as adversaries seeking to curtail business.
Optimum Timing for Property Divestment
Authors: Rosiere D. W. 
Published: December 2007

ABSTRACT
An economic analysis technique has been developed to aid in determining optimum divestment time for oil and gas properties. This technique can be a useful planning tool in defining the operation and divestment portfolio of a maturing property base, and can be programmed within a computer spreadsheet using data extracted from only one economic forecast of continued operations.
The technique identifies the optimum time to divest by comparing at each remaining year of economic life, "the net gain that would be realized from sale" to "the net present value (NPV) of continuing operations for one more year, plus the net discounted gain from sale at the end of that year." In other words, the analysis addresses at the beginning of each remaining year, "Is it moire profitable to sell now, or operate for another year and then sell?"
Optimum divestment time can be determined graphically or from tabulated comparison values. Cumulative differences in comparison values for each year can show expected loss from divesting at times other than optimum. If property divestment is imminent, the comparison can be used to determine a minimum sales price that yields maximized economic gain compared to continued operations.
Division of Technology Ownership Between a Service Company and Customer
Authors: Daunis J. R. , Scott F. L. 
Published: December 2007

ABSTRACT
This paper discusses the increased emphasis on division and allocation of ownership, costs and risks associated with technology rights and Intellectual Property (i.e. intangible assets such as patents, trademarks, copyrights, computer programs or software, trade secrets and other technical know how and show how) between a Service Company supplier of oil and gas products and services, such as Halliburton Company, and a Customer, such as Atlantic Richfield Company. There is increasing industry wide interest in Strategic Alliances between Service Companies and Customers. Atlantic Richfield Company and Halliburton Company have recently entered into such a Strategic Alliance. One of many aspects of such an Alliance includes an allocation of the ownership of Intellectual Property Rights related to or resulting from the working relationship between the Service Company and the Customer.
Fracture Characterization From Measured and Simulated Bottom hole Pressure
Authors: Fragachan F. E. , Mack M. G. , Nolte K. G. , Teggin D. E. 
Published: December 2007

Abstract
This paper presents analyses of fracturing pressures measured, through a dead-string completion, in ten wells located in northern Mexico. Measured pressures are simulated with a novel pseudo-three-dimensional (P3D) model, matching the observed field data. Closure pressure is derived from a combination of a "step-rate" test, performed at the beginning of the treatment, and analysis of the pressure decline observed at the end of the treatment (closure on the proppant provides an upper bound to the closure pressure).
One well is discussed where bottomhole pressures were observed to be higher than the overburden, and indicated a fracture also propagating in the horizontal plane ("T" fracture). Two other wells showed a wellbore screenout as soon as proppant hit the perforated interval. Finally, a well where a tip-screenout was observed is considered.
Conclusions and recommendations are provided regarding the analyses of fracturing pressures and their importance for understanding and improving the fracturing process.
Numerical Simulation Study of Water Shut-Off Treatment Using Polymers
Authors: Hwan R-N. R. 
Published: December 2007

Abstract
Polymers are frequently used to treat high water-cut producing wells in an effort to reduce water production. The application of polymer solution was reported to be successful in some cases but disappointing in others. This study applies numerical simulation to investigate the effectiveness of the polymer treatment for reducing water production from oil wells with water coning and from waterflood producers.
The results of the study show that near-wellbore, non-gel type polymer treatment in lowering water production can only be effective for a period of time. The water production will gradually rise to and exceed the pre-treatment level. An effective treatment requires deep polymer penetration in the formation to reduce water coning and the water production from waterflood producers. Water coning heightens at high production rates, low perforation intervals, high oil-water viscosity ratios, etc. The polymer treatment is not very effective for the wells with severe water coning problems.
Fracturing Fluid Leakoff and Damage Mechanisms in Coalbed Methane Reservoirs
Authors: Conway M. W. , Penny G. S. , Schraufnagel R. A. 
Published: December 2007

ABSTRACT
Fracturing fluid leakoff in coalbed methane reservoirs can be highly damaging to the cleat permeability of coal. During the fracturing treatment, the cleats sub-parallel to the fracture are thought to open and accept fluid. Laboratory and field evidence suggests that severe damage can result deep within the formation. This work investigates mechanisms of fluid leakoff, damage and control in large scale cleated coal samples and in coal core samples from the San Juan and Black Warrior Basins. The leakoff properties, regained permeability and retained conductivity of the proppant pack have been studied with various cleat orientations and fluid loss additives, including 100 mesh sand. The damage of various fracturing fluids has been further measured vs penetration depth in fresh coal cores from the Black Warrior Basin in a multiport core flow apparatus.
Three damage mechanisms have been identified including 1) leakoff of whole gel during spurt or uncontrolled leakoff, 2) leakoff of water only during filter cake control prior to breaking and 3) leakoff of broken polymer while breaking. The application of 100 mesh sand can control leakoff to cleats: however, the cleats and pack only cleanup if appropriate breakers are applied. Leakoff of water only with filter cake control is the least damaging mechanism to cleat permeability. Finally, the leakoff of broken guar is as damaging as whole guar due to polymer adsorption onto coal surfaces; experimentally modified guars that show minimum adsorption are less damaging.
Quantifying Layered Reservoir Properties With a Novel Permeability Test
Authors: Jochen J. E. , Hopkins C. W. , Frantz J. H. 
Published: December 2007

ABSTRACT
This paper presents a new test procedure designed to measure individual layer reservoir properties (permeability, skin factor, and reservoir pressure) in a single wellbore and in a reasonable amount of time for low permeability gas wells. The method involves (1) isolating a small interval with packers, either in an open- or cased-hole, (2) injecting nitrogen into the interval at a rate such that the bottomhole pressure builds up to a pre-determined value (below fracturing pressure), and (3) shutting in the well, preferably downhole, and monitoring the pressure falloff. The pressure falloff data is then analyzed to determine reservoir properties. Essentially, this method can be described as a nitrogen slug test and can be applied to any formation where single-phase gas is produced.
We have found that average reservoir properties determined with conventional analyses of a single pressure buildup test conducted over a large interval can lead to optimistic predictions of the future performance of a well producing from a layered reservoir system. Therefore, being able to quantify individual layer properties can lead to better reservoir characterization, modified completions, and improved performance projections. Existing techniques, such as multiple pressure buildup tests, are inadequate for measuring reservoir permeability in several intervals in a single wellbore because, often in low productivity gas wells, either a pre-stimulation rate is not attained or the time required to reach the correct semilog straight line for a conventional well test analysis is too long. Knowledge of layered reservoir properties impacts completion decisions (where to perforate), fracture design considerations, and post-fracture analyses.
Openhole DST of a Horizontal Well: A Case Study
Authors: Finley D. B. , Wendler C. E. 
Published: December 2007

ABSTRACT
The last several years have seen an increase in the popularity of horizontal wells1. There are a number of applications for horizontal wells that are an enhancement to the traditional vertical well. By increasing the wellbore's contact area with the reservoir, a horizontal well increases the drainage efficiency of a marginal reservoir by: more efficiently exploiting naturally fractured formationsreducing the likelihood of water coning and/or fingeringimproving EOR via horizontal injection wellsintersecting vertical or near vertical formations
To determine if a horizontal well will indeed provide the intended enhancement to productivity (or injectivity), an evaluation of the formation parameters and characteristics is recommended.
Drill stem testing of vertical wells has long been a popular means of formation evaluation. However, the testing and subsequent formation evaluation of a horizontal well presents additional challenges. The successful operation of the downhole tools as well as the analysis of the collected data are not as straightforward as for a vertical well.
This paper presents a case study of the successful testing and subsequent analyses of four open hole DSTs of a horizontal well. These DSTs were conducted during the well's drilling phase at ever increasing degrees of deviation; from ±45 degrees for the first test to ±90 degrees for the fourth test. This paper presents and discusses the: downhole tools used and their relative positions in the holeplanning and preparation for the testsanalysis of the collected data for formation parameters and characteristicsaspects of the horizontal hole that affected the analysis.
Scale Dependence of Mechanical Properties: Application to the Oil and Gas Industry
Authors: Schatz J. F. , Schatz John F. , Olszewski A. J. , Schraufnagel R. A. 
Published: December 2007

ABSTRACT
A method and underlying mathematical model are introduced for determining the size scaling and frequency sensitivity of mechanical properties. The method allows laboratory triaxial and ultrasonic data, as well as log data such as the dipole sonic log, or a subset of these, to be used for determining static moduli on a larger scale. Applications are in hydraulic fracture design, in-situ stress estimation from logs, and wellbore/formation deformation studies. The model is based on soft discontinuities and inhomogeneities as the primary causes of scale effects in geologic media. Because of its basis in physical mechanisms, the model has the potential of being more widely applicable than if it were purely empirical. A computer program is developed to allow easy data reduction and application. Validation is performed with lab and field data at five different depths and rock types from a coalbed methane well.
When Can a Fracture Be Initiated Through a Circular Wellbore in an Oil Sand Reservoir?
Authors: Wang Yarlong , Dusseault M. B. , Chhina Harbir 
Published: December 2007

Abstract
Oil sands and other poorly consolidated sandstones (PCS) behave differently under different loading procedures, and retain memory of their load histories in the three-dimensional array of contacts and forces. These factors complicate predictions of the response of PCS to external loadings. Prediction of hydraulic fracture initiation pressure in a PCS is difficult, as fracture initiation depends on in situ stress state, material constitutive behavior, and ultimately may be controlled by stress path and history. In this paper, load paths corresponding to certain field activities and laboratory tests during pumping and injection are analyzed to evaluate cases that arise when hydraulic fracture initiation is attempted in a PCS reservoir. Fracture initiation pressures following different loading paths are presented by applying elastic and elastoplastic models. Hydraulic fracturing tests conducted in oil sands in the Cold Lake region in Alberta are used as examples. The bottomhole pressure records are used to compare with our analytical results.
The conclusion is that, for the same in situ stress, wellbore hydraulic fracturing pressure records in a PCS may respond totally different when different stress paths have been followed. This load history of a wellbore environment depends on drilling and pressurization history. Conventional elastic equations for predicting fracture initiation pressures are not appropriate; one must in general interpret wellbore pressure records for hydraulic fracture in PCS using elastoplastic models, incorporating material properties and loading history.
UNAVAILABLE - Decline-Curve Analysis With Type Curves - Analysis of Gas Well Production Data
Authors: Palacio J.C. , Blasingame T.A. 
Published: December 2007

This paper is not available.
It was an oral presentation at the SPE Rocky Mountain Regional/Low Permeability Reservoirs Symposium, held in Denver, Colorado, 12-14 April, 1993. The authors did not provide the manuscript or copyright permission for addition to the proceedings.
Analytical Upscaling of Small-Scale Permeability Using a Full Tensor
Authors: Aasum Yngve , Kasap Ekrem , Kelkar Mohan 
Published: December 2007

ABSTRACT
Computational costs limit large scale reservoir simulations to coarse grid systems. Determination of an effective permeability for a simulation grid block requires a proper scale-up of small scale permeability heterogeneities within that grid block. Conventional scale-up techniques are limited to a diagonal tensor representation of effective permeability. Therefore, such techniques cannot handle general permeability anisotropy (full tensor) exemplified by cross-bedded permeability structures that may be present on a smaller scale. An analytical method is developed to calculate an effective permeability tensor for a grid block by accounting for small scale heterogeneities within the grid block. The method honors both the location and the orientation of the small scale heterogeneities. Effective permeability tensors calculated using the analytical method and a numerical method show excellent agreement. Miscible displacement simulations show that the effective permeability tensor method outperforms conventional scale-up techniques in predicting flood front locations in cases of general permeability anisotropy.
Economic and Environmentally Beneficial Reuse of Drilling Waste
Authors: Longwell H. J. , Grieve D. V. , Raque A. K. 
Published: December 2007

ABSTRACT
Mobile Bay drilling operations are conducted under strict "zero discharge" of drilling and completion fluid wastes. This regulatory constraint challenges drilling operators to develop waste management systems for the collection, treatment, and onshore disposal or reuse of these wastes.
This paper presents a generally applicable, multi-step process used in the development of a successful drilling waste management plan, and proposes the reuse of treated drilling wastes as municipal landfill daily or intermediate cover material.