bluuebunny/crossref_metadata_2025_split huggingface dataset:
Evaluating Casing Deformation Mechanisms in Primary Heavy Oil Production
Authors: Wagg B. , Xie J. , Solanki S. , Arndt S. 
Published: December 2007

Abstract
Massive sand production during primary heavy oil recovery operations in Northeastern Alberta has resulted in severe deformation of the well casing in a number of wells. A new method for processing multi-sensor caliper data has allowed heavy oil operators to map local casing deformation features such as collapses, buckles and shears that are too localized to be identified with conventional gyroscope surveys. The processed caliper data are used to benchmark numerical simulations of the casing/formation interaction. The formation movements predicted from these simulations are used to infer the geometry of the sand producing zone and can be used to evaluate the effectiveness of a variety of mitigation strategies.
Construction Of Underground Storage Chambers
Authors: Loofbourow R.L. , Wood Wm. G. , Lassiter R.T. 
Published: December 2007

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, with the paper, may be considered for publication in one of the two SPE magazines.

Abstract
Many of the large market areas, near which there is no "natural" storage, can be served from storage in large, deep excavations. We discuss the conditions needed and where they are expected, the appropriate mining plant and methods, the environmental effects, cost and time and the advantages attainable.

Introduction
We are miners. We won't take time to tell you that gas storage is needed near many large markets. You know that better than we. You know the security of conventional underground storage. You know the capital costs and limited flexibility of surface storage and the opposition to it.
We expect you will appreciate the advantage of a storage into which you can put gas and from which you can recover it put gas and from which you can recover it at rates limited only by the design.
We remind you that natural gas has been stored in an unused coal mine north of Denver, in salt cavities in Michigan, Saskatchewan, Texas and Mississippi, and that pressurized butane, propane and ethane liquid and gas are held at more than 60 sites, in underground excavations in many kinds of rock. We believe that none of these storage spaces has any sort of lining. Each type has been in use from 10 to 25 years.
Please remember that the use of underground space is not new. Some of our prehistoric ancestors appreciated its advantages. The first space used was provided by Nature. However the spaces provided by Nature. However the spaces she provides are not always what your public needs nor where they need it. public needs nor where they need it. We shall show you what miners can provide and some of the tools.

BASIS OF MEG CONCEPT
Our concept is bassed on these related coincidences:Strong rock is a fine medium for large stable, low-unit-cost excavations
Natural Gas Supply Situation (May 1975)
Authors: DeLaMater Stephen T. 
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.
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, with the paper, may be considered for publication in one of the two SPE magazines.

Abstract
This paper analyses the factors which will influence the future of gaseous fuels in the United States. The gas industry faces several interrelated problems which have combined both to create the present natural gas shortage and to delay finding solutions to it. The base reason for the shortage is almost universally conceded to be the misapplication of Federal regulation of the wellhead price of gas. Confusing the issue, however, are a general lack of understanding, at the decision making level of government, as to the significance of gaseous fuels to our economy, and a misconception as to the feasibility of alternatives. Discussed are factors which will affect future trends in fuel usage, the importance of natural gas supplementals, the economic impact of an extended severe gas shortage, the need for increased new gas exploration, the availability of new gas supplies, the limitations of the "all electric" argument, and the case for deregulation. This paper concludes that there must be a national imperative for a continuity of our gaseous fuel supply.

IMPORTANCE OF GASEOUS FUELS
The people of the United States, after more than a year and a half of "shortages" and crisis talk, still do not understand the real dimensions of the energy situation. They view the predicament almost solely in terms of predicament almost solely in terms of Mideast oil and its dollar-wise impact on gasoline prices and electricity bills.
Inclination at the Bit Improves Directional Precision for Slimhole Horizontal Wells: Local Case Histories
Authors: Varco Martin , Smith James E. , Stone Dan M. 
Published: December 2007

Abstract
In the 10 years plus of horizontal drilling, productivity improvements and cost reductions have been the result of reducing the hole sizes and geosteering the wells within a specific productive horizon. Drilling programs within the Prudhoe Bay unit (PBU) are targeting thin oil intervals sandwiched between overlying gas and underlying water boundaries. Economic constraints related to the high cost of reaching the reservoir have dictated that each well must access multiple targets over longer horizontal segments. Most of these targets are defined by sealing fault boundaries that produce vertical offset ranging from 10 to 70 ft. Considerable precision in vertical wellbore placement is required to evaluate and then redirect true vertical depth (TVD) placement of the borehole with each fault crossing. Failure to rapidly correct for fault offset produces a low-value horizontal hole. The 4 ¾-in. AIM* At-Bit Inclination Measurement tool, developed for use with an advanced triple combo logging system, delivers directional precision previously possible only in larger hole sizes. This system has been used in PBU to drill complex 3D directional wells, land them to within 1 ft TVD of the required target and then to drill for lengths of over 5000 ft with a similar degree of accuracy. The bit rate of penetration (ROP) of the horizontal section has also increased because the amount of slide time required for wellbore placement corrections is reduced by early detection of steering results using the at-bit measurements.
Inelastic Capture Neutron Logging to Identify Bypassed Hydrocarbon in Complex Secondary-Recovery Environments
Authors: Hupp Douglas , Kasecky Mike , Ohms Danielle , Warner Dwight 
Published: December 2007

Abstract
Inelastic capture neutron logging (IC) has been used successfully to identify water influx and by-passed hydrocarbon in the mature oil fields located on the North Slope, Alaska. The North Slope has had commercial production since 1977. Production from these fields are enhanced by secondary recovery techniques including water flooding using Beaufort Sea and produced water, natural gas re-injection and miscible fluid injection techniques. The uses of traditional cased-hole evaluations (sigma and porosity interpretation from pulse neutron and cased hole neutron logs) are limited due to the complexity of the secondary recovery techniques including wide variations in the salinity of injected water. Beaufort Sea water salinity varies widely through out the year due to the influx of fresh water during the spring run off. Inelastic capture neutron logging and interpretation has allowed identification of remaining and by-passed oil and has aided in the planning of sidetrack wells to tap additional reserves. Ambiguities arising out of formation water salinity uncertainties have been clarified through the use of inelastic capture neutron logging techniques.
Acid-Sludge: How Small Particles Can Make a Big Impact
Authors: Rietjens Marcel , Nieuwpoort Marco 
Published: December 2007

Abstract
Acid-induced sludge, a major source of well damage, can vary from a viscous, stable emulsion to the product of a polymeric reaction. This paper examines the nature of sludge and how it is formed.
Sludge particles are often believed to be large, but research shows that the molecular weights of the constituents of sludge particles are relatively low. In size-exclusion chromatography tests, sludge was dissolved in a solvent and analyzed. Results showed that the mass of sludge constituents was only twice that of the highest molecular weight of the oil components. In undiluted pure oils, however, sludge particles were much larger than particles of the constituents; individual sludge particles are even visible by microscopy.
A chemical analysis of sludge shows that hydrochloric acid (HCl) is present in the sludge structure but water is not. Besides HCl, Fe(III) ions in HCl formulations can cause a large amount of sludge. Even though ferric ion could not be detected in the oil phase or in the sludge, it induces sludge mainly because it works as a phase-transport catalyst for HCl.
Sludge is an aggregate of protonated molecules. Aggregation is initiated by protonation of asphaltenes and other compounds, such as resins, that undergo acid-base interactions. Molecules are then formed that have surfactant-like properties that tend to form structures resembling reversed micelles. Stack formation, which occurs in asphaltene aggregation, is another initial mechanism for aggregation of protonated constituents. These initial aggregates eventually become a flocculate, or sludge.
The aggregation theory seems to be supported by the fact that a critical aggregation concentration exists, below this concentration level, sludge will not form; above this concentration level, sludge is formed in increasing amounts.
This paper shows that sludge can be dissolved in pure solvents or in nonsolvents containing surfactants, demonstrating that sludge formation is reversible.
Production and Cost Optimization for Sand Control Completions over Thick Reservoir Sections: Application to Two Fields in West Africa
Authors: Petit G. , van Domelen M. L. 
Published: December 2007

Abstract
Selecting the optimum sand control technique for reservoirs with large vertical thickness and long wellbore lengths through the pay zone is currently a topic of widespread discussion in the industry. The selection is made by comparing the expected productivity of the completion procedure with the cost. The decision is made difficult because some very important reservoir parameters such as permeability, damage, oil properties, and layering sometimes only become known during the completion phase.
This paper gives the overall results of fourteen producing oil wells that were completed in two offshore fields in West Africa using the frac-and-pack sand control technique. The wells had deviations of up to 61°. These wells have moderate production levels (around 2,000 bopd/well) and have multiple layers, spread over 200 to 350 ft gross interval lengths. One aspect of this paper will be to describe the efforts made to quantify the relative costs between various sand control techniques, taking into account such factors as material costs, rig times, and equipment requirements, and how these cost assessments were then weighed against expected completion efficiencies.
When designing the treatments, some important guidelines were also established regarding how to group layers together for a single treatment, how to open the perforations before the frac treatment, how to model fracture growth in these deviated wells with possibly more than one interval perforated, and the actual completion procedure. A review of the different well results is presented with the objective to better understand the impact on the productivity of different factors such as deviation, interval length, completion and sand control practices.
Effect Of Porosity On Depth Of Investigation Of Neutron And Density Sondes
Authors: Sherman H. , Locke S. 
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.
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, with the paper, may be considered for publication in one of the two SPE magazines.

Abstract
Depths of investigation of a Density tool and several versions of Neutron tools hate been measured experimentally at a porosity of 22 percent in quartz sandstone. Comparisons with earlier results in 35-percent-porosity sandstone indicate little change in depth of investigation over this porosity range. The results also illustrate dependence of depth of investigation on casing and cement, neutron-source energy, relative change in hydrogen content, and presence of thermal-neutron absorbers. presence of thermal-neutron absorbers.
History of Development of the Tijerina-Canales-Blucher (Zone 21-B) Field High Pressure Extension Area
Authors: Harris Gregg A. 
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.
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, with the paper, may be considered for publication in one of the two SPE magazines.

Abstract
This paper presents (1) the results of a combined engineering/geological study that led to the discovery of several million barrels of additional oil in the nearly 30 year old Tijerina-Canales-Blucher (21-B) Field oil column; (2) the results of a two-dimensional, three-phase computer simulation study of the reservoir; and (3) a comparison of actual versus predicted performance. The new oil area was discovered in late 1972 by drilling Exxon's King Ranch-Tijerina Well A-29 to investigate a possible stratigraphic trap suggested by an observed anomalous high pressure area. Twenty additional wells were drilled before extent of the new oil area was known. A computer model simulator study was made to predict future performance, to determine an predict future performance, to determine an optimum water injection program, and to determine if producing rates were compatible with maximum oil recovery.. The oil reserves are now essentially depleted and a favorable comparison can be made between actual and predicted performance. Additional oil reserves predicted performance. Additional oil reserves developed in the high pressure extension area are estimated to be 3.9 million barrels. Fifty-two percent of the oil in place will be recovered, and a volumetric sweep efficiency of 85 percent is indicated.

Introduction
The Tijerina-Canales-Blucher (21-B) Field is located about 12 miles southwest of Kingsville in South Texas. As shown in Figure 1, this field is situated at the southern end of the Zone 21-B Trend Field, which consists of a large gas cap with several rim type oil columns. Prior to 1975, the Zone 21-B Trend Field had been prorated by the Texas RRC as three separate fields-Borregos, Seeligson, and T-C-B Fields. The T-C-B oil column, which was discovered in 1944, is located along the southern and eastern rim of the structure and was developed by drilling in the 1940's, 1950's, and 1960's. Exxon developed its portion of the oil column with about 110 wells on 40-acre spacing.
The 21-B sand in the T-C-B field is located at an average depth of 7,000 feet subsea and is composed of four sand stringers which are in communication with one another in certain areas of the T-C-B field. Sand quality is good as porosity averages 25 percent and permeability averages 186 mds. percent and permeability averages 186 mds. Primary drive mechanism is gas cap expansion Primary drive mechanism is gas cap expansion which has been supplemented by gas and water injection.
Physical Observations and Mapping of Cracks Resulting from Hydraulic Fracturing In Situ Stress Measurements
Authors: Tyler L.D. , Vollendorf W.C. 
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.
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, with the paper, may be considered for publication in one of the two SPE magazines.

Abstract
For many years hydraulic fracturing has been used as a stimulation tool for oil and gas reservoirs. Hydraulic fracturing has also been developed as a method to measure in situ stresses. The correspondence between the measured fluid pressures and the in situ stresses has been studied and is fairly well understood. The characteristics of the fractures created by hydraulic fracturing are not understood. Information about the fractures at the wellbore can be obtained by a number of techniques but knowledge of the fractures behavior away from the well is very limited. The fracture behavior may determine either the stress direction for a stress measurement or the difference between a good or bad stimulation job.
To better understand the hydraulic fracture technique, experiments were performed in a tuff formation in Rainier Mesa performed in a tuff formation in Rainier Mesa at the Nevada Test Site. The purpose of the experiments was to determine the stresses in the mesa; and, to examine the fracture behavior produced by the hydraulic fracture technique. Hydraulic fracturing was performed in both vertical and horizontal performed in both vertical and horizontal boreholes with a maximum overburden of 1490 ft. All experiments were done in the vicinity of an existing tunnel complex but sufficiently remote to avoid unwanted boundary effects. The stresses were determined from the hydraulic fracture data using the theory of Fairhurst and Haimson. The maximum horizontal, vertical and minimum horizontal principal stresses for 1365 ft. of overburden principal stresses for 1365 ft. of overburden were 1788 psi, 1183 psi, and 1015 Psi, respectively. A number of the fractures produced during the tests were mapped by produced during the tests were mapped by mining from the tunnel complex and physically examining the fractured formation. physically examining the fractured formation. Dyed water was used for all the holes drilled in the tunnel complex. Dyed cement grouts were used to tag the fractures formed in a 1365 ft. deep hole from the top of the mesa. Two fracture jobs were performed at two locations in the vertical hole using yellow and red grouts. These fractures were essentially vertical and parallel.
A Heuristic Approach to Drilling Optimization
Authors: Tansev E. 
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.

Abstract
This paper presents a new approach in formulating and solving the optimal drilling problem. The approach is heuristic as it involves the interaction of raw data, regression and an optimization technique. From several bit runs regression equations were established for predicting penetration rate and bit life. Three control variables are accounted for: weight on bit, rotary speed and bit hydraulic horsepower. The equations for penetration rate and bit life are incorporated into a drilling cost equation and the cost function is minimized over the control variables. These variables then dictate the optimal drilling of the next bit run.
A uniform formation drilled with similar bits and an on-line optimization scheme for updates with each new bit run, is best suited for this approach. An application of the procedure to field data is given.

Introduction
Numerous publications over the years have contributed to the complex subject of drilling optimization. Concentrating on some of the recent publications that offer a mathematical model for drilling, publications that offer a mathematical model for drilling, Reed devised a Monte Carlo technique to solve the variable weight-speed problem. He concluded that it offers very little advantage over the simpler constant weight-speed approach. He then presented a solution to the constant weight-speed problem based on the conjugate-gradient method. Reed used nearly the-same set of empirical equations Young proposed, as a set of differential constraints in the context of minimization. Interestingly we found no significant difference in comparing several examples reported by Reed with solutions by Young's formulation. Wilson and Bentsen applied several optimization techniques to minimize drilling costs. In their "Multi-interval Optimization", dynamic programming was used to optimize the intervals drilled and programming was used to optimize the intervals drilled and the minimum of the total cost function indicated where to change the bit. They have used the equations derived by Galle and Woods in their modeling. Some theoretical analysis that include the stress properties of the formations was carried out by properties of the formations was carried out by Wardlaw. Polynomial-type functions were derived from dimensionless groupings of variables according to categorized drilling conditions. Minimization of the drilling cost function was achieved by geometric programming. programming. There appear to be some drawbacks in common to each of these approaches. These can be listed as:Several formation and bit parameters must be known in advance. These are determined from analytical expressions, from previous data, field testing or from experience and judgement;Only bit weight and rotary speed are fully accounted for as control variables.
Review of Thermal Recovery Methods
Authors: Dietz Daniel N. 
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.

Abstract
Oil displacement is less than perfect because despite driving forces - part of the original oil in place is retained by capillary and by viscous forces. The viscous forces can be reduced by heating the oil in place. Most of the heat is inevitably taken up by the oil sand, interbedded shales and cap- and base rock. The heat is therefore used most efficiently where a maximum of thermally recoverable oil is tied to a minimum of rock (heavy oil, high porosity etc.). The economy may be improved by recuperating heat from swept formation for repeated use.
Besides reducing the retaining forces, thermal drive also enhances the driving forces because many reservoir volumes of hot water, steam or air are required to displace one volume of oil. For steam and air this enhancement is stronger the lower the pressure.
In the initial phase, when the oil is still cold, it may be hard to obtain satisfactory circulation and special well patterns with a high number of producers per injector (inverted 9 spot, 13 spot) are sometimes used. These patterns also minimize pressure later on. Heat stimulation of producers is also used to facilitate start up. producers is also used to facilitate start up. Where heat recuperation is applied, the recovery-efficiency of the heat should also be considered and an overall sweep from the reservoir boundary may be preferred over a pattern flood.
The heat may be applied from the surface by specially designed hot water heaters or steam generators. The injectors are subjected to high thermal stresses and in old fields, where more often than not additional wells have to be drilled, the new ones are invariably used as injectors.
The compressed air for in situ combustion requires more expensive surface installations, but less fuel than hot water or steam. Heat recuperation is more efficient in combustion projects because it can be done continuously projects because it can be done continuously by simultaneous cold water injection. Wet combustion, with its double injection system requires more engineering than any other thermal drive: determination of optimum water/air ratio, evaluation of corrosion danger and where necessary its prevention.