bluuebunny/crossref_metadata_2025_split huggingface dataset:
Drilling and Production Practices To Mitigate Sucker Rod/Tubing Wear-Related Failures in Directional Wells
Authors: Matthews C. M. , Dunn L. J. 
Published: December 2007

Summary
When the Lindberg heavy-oil field in Alberta was being developed in the early 1980's, frequent wear-related workovers were experienced in wells directionally drilled from central pads. Four operating companies collaborated with the Centre for Frontier Engineering Research (CFER) in a field study organized to investigate these failures and determine techniques to extend production equipment life. The study included monitoring of rod and tubing wear and production parameters in more than 50 directional wells. Results showed that wellbore configuration had a strong and consistent effect on the wear rates of downhole equipment in directional wells. It also was demonstrated that local curvature variations, which led to wear-related failures in several wells, could be attributed to drilling and surveying practices. This paper offers guidelines on wellbore geometry design to optimize the performance of mechanical lift systems and presents field-based results on the effectiveness of wear-reducing equipment. It also makes recommendations regarding an operational program designed to minimize wear-related failures. The development and application of a model capable of predicting rod loads and tubing wear in directional or horizontal wells also are described.
Fracture Tip and Critical Stress Intensity Factor of a Hydraulically Induced Fracture
Authors: Yew C. H. , Liu G. H. 
Published: December 2007

SummaryBy modeling the rock as an elastoplastic solid obeying the Drucker-Prager failure criterion, we have demonstrated that, if the dilatation produced in the plastic zone in front of the fracture tip is inhibited by its surrounding elastic material, the critical stress intensity factor, KIc, of the material can be higher than those obtained from standard laboratory tests. Using Geertsma's fracture model and including the dry zone in analysis, we also have demonstrated that, unless the fracture is very large, the fracture opening width is affected by the KIc. of the material.
NORM Contamination in the Petroleum Industry
Authors: Gray P.R. 
Published: December 2007

Summary
Contamination of oil and gas facilities with naturally occurring radioactive materials (NORM) is widespread. Some contamination may be sufficiently severe that maintenance and other personnel may be exposed to hazardous concentrations. Contamination with radium is common in oil-production facilities, whereas contamination with radon and radon decay products is more prevalent in natural-gas production and processing facilities. Although largely unregulated until recently, U.S. states, notably Louisiana and Texas, have or are enacting legislation to control NORM contamination in the petroleum industry.

Introduction
NORM contamination can be expected at nearly every petroleum facility. Some of it can be sufficiently severe that maintenance and other personnel may be exposed to hazardous concentrations. In addition, the industry must comply with new regulations. Mississippi and Louisiana have enacted legislation to control NORM; Texas will have regulations early in 1993; and other states, as well as Canada, can be expected to have similar regulations shortly.
Two general types of common NORM contamination will be controlled by these regulations.Radium contamination of petroleum production facilities - specifically of pipe scale and sludge and scale in surface vessels. In addition, produced water may be radioactive from radium dissolved in underground water.Radon contamination of natural-gas production facilities. This includes contamination with the long-lived decay products of radon. Facilities that remove ethane and propane from natural-gas facilities are especially susceptible to NORM contamination.
Naturally occurring radionuclides are widespread in the environment. In many geologic formations, radium, radon, and other radioactive elements are associated with oil and gas. When oil and gas are produced, traces of these radioactive elements also are produced. When the formation water contains traces of radium (radium-226, a decay product of uranium, and radium-228 from thorium), scale in the production pipe can become radioactive, sometimes containing several thousand picocuries of radium per gram of scale. The radioactivity results when radium coprecipitates with barium and strontium sulfates in the scale formation.
Reservoir Description Detail Required To Predict Solvent and Water Saturations at an Observation Well
Authors: Stalkup F. I. , Crane S. D. 
Published: December 2007

Summary
This paper describes the reservoir simulator analysis of an observation-well pilot test in the Prudhoe Bay miscible flood. It shows that 1-ft simulator layers and explicit representation of thin, discontinuous shales are required to predict solvent occurrences and log-derived water and solvent saturations at the observation well. The predictions show that solvent flows past the well in numerous tongues that are only a few feet thick.
Analysis of a Steam Drive Project, Inglewood Field, California
Authors: Blevins T.R. , Aseltine R.J. , Kirk R.S. 
Published: December 2007

This is the first reported California field data on the vertical extent and residual oil saturation of the steam swept zone. Field-derived data on reservoir heat distribution support the published theoretical data.
The Inglewood field, discovered in 1924, occupies a faulted anticline along the Newport-Inglewood Fault System on the western edge of the Los Angeles basin (Fig. 1). The Upper Investment zone, UB sand, selected for this test is the shallowest producing reservoir in the field and lies about 1,000 ft below surface ( 650 subsea). The UB sand productive limit are defined by an updip sand pinchout, the Inglewood Fault, and by down-dip water.
The UB sand is 40 to 60 ft thick, consists of fine- to coarse-grain sand with occasional pebbles, ranges from soft to unconsolidated, is overlain by a thick siltstone section and has bottom water. The reservoir properties are shown in Table 1, and electric log characteristics in Fig. 2. The air permeability ranges from 3.3 to 14.3 darcies in the top 40 ft of the reservoir, and porosity averages 39 percent. The primary producing mechanism is pressure depletion with primary producing mechanism is pressure depletion with water encroachment. Oil in place at start of project was 1,930 bbl/acre-ft. The Investment zone oil is asphalt base, 14 degrees API gravity with an in-situ viscosity of 1,200 cp.
The high oil viscosity, low reservoir pressure, shallow depth and high oil saturation are all favorable for application of thermal recovery methods. Preliminary laboratory studies of steamflooding in Inglewood cores indicated that residual oil saturations of approximately 20 percent could be achieved with throughput of 1 PV of water converted to steam.
Chevron Oil Field Research Co. and Standard Oil Co. of California, WOI conducted the Investment zone lost to learn if the low laboratory residual saturations could be obtained in the field and to determine the oil displacement efficiency in the project area. The test was designed to obtain data on vertical and areal coverage, heat losses, and rate of steam front advance, and to evaluate producing problems associated with continuous steam injection.
Design Project Area Project Area Fig. 3 shows the steamflood pilot layout. It is an inverted six-spot containing 2.6 acres within the five first-line producing wells. The project area of the reservoir has essentially no dip. Injection Well 270 and Temperature Observation Wells 271, 272, 273 and 293, were newly drilled for the project. The location of Wells 304 and 304A, which were drilled specifically to obtain post-steam saturation, is also shown in Fig. 3.
A Case History of the Pegasus Ellenburger Reservoir
Authors: Cargile Leslie L. 
Published: December 2007

The performance of the 13,000-ft-deep Pegasus Ellenburger in West Texas has shown that, even in an extremely heterogeneous reservoir, gravity segregation drive can be an efficient producing mechanism.

Introduction
The Pegasus field is a large multizone field in Midland and Upton Counties, Tex. Oil productive intervals have been found in the San Andres, Spraberry, Pennsylvanian, Devonian, Fusselman and Ellenburger zones. The Pegasus Ellenburger is the deepest reservoir at an average depth of 13,000 ft and is also the most prolific oil producer. Since discovery in 1949, over 60 million STB of oil have been produced from this reservoir. The 4.5 million STB produced in 1967 was the highest annual oil production during the life of the reservoir. As production during the life of the reservoir. As of April, 1968, the reservoir pressure was more than 1,100 psi below the bubble point and the producing GOR had not significantly increased. producing GOR had not significantly increased. Development and Unitization
Magnolia Petroleum Co. (now Mobil Oil Corp.) drilled and completed TXL "A" Well No. 1 as the discovery well in the Pegasus Ellenburger field. This well, which is now the Pegasus Ellenburger Unit Well No. 15-1, was drilled in March, 1949, to a total depth of 13,295 ft, with a potential of 1,167 BOPD flowing with over 1,000 psig tubing pressure. From 1950 to mid-1954 the field was pressure. From 1950 to mid-1954 the field was developed at an average rate of 24 wells/year. In all, 119 wells have been drilled. The Pegasus Ellenburger unit became effective June 1, 1954. Fig. 1 shows the location of wells and the unit boundary.
Production and Injection History Production and Injection History Fig. 2 shows the oil and water production history, water and gas injection history, and GOR performance. The sharp decrease in oil production in 1951 resulted when the allowable was reduced from 395 to 200 B/D/well to allow time to initiate pressure maintenance operations before the bubble-point pressure was reached.
Pilot water injection was begun in 1955 and expanded in 1959 to a full-scale peripheral injection program. In 1960 the allowable was increased to 435 B/D/well (the 1947 yardstick value for 80-acre spacing). Water injection performance did not prove efficient and, in performance did not prove efficient and, in 1963, injection rates were curtained so that the effects of continued pressure decline could be observed. Gas injection was begun in 1967 and expanded to a full-scale crestal gas injection program in early 1968.

Geology
Structurally, the Pegasus Ellenburger reservoir is a three-domed anticline with a general northeast-south-west axial trend. (See Fig. 3.) The production area encloses almost 10,000 acres. There are major faults along the east and west sides of the field, and it is believed that numerous other faults (having smaller displacements) also exist throughout the field.
JPT
P. 1330
Scaled Model Studies of Thin Oil Columns Produced by Natural Water Drive
Authors: Khan A.R. , Caudle B.H. 
Published: December 2007

Abstract
The oil production performance of thin-oil-column type reservoirs producing entirely by natural water drive are discussed in this paper. The dimensionless production histories were obtained in a series of production histories were obtained in a series of scaled porous-medium laboratory-model tests under varying effects of rate of production, mobility ratio across moving boundary, ratio of oil- and water-sand thickness and mobility ratio across fixed boundary including the effects of different residual oil saturations in the water-invaded regions. This scaled-model study of thin oil columns indicated that greater recovery of oil results for lower values of the following: rate of production, mobility ratio across the moving boundary, water-sand thickness relative to the oil-sand thickness, and mobility ratio across the fixed boundary or residual oil saturation in the water-invaded region of oil sand The results of the study are given as dimensionless production history plots which may be used to production history plots which may be used to predict the performance of the field they represent.

Introduction
Oil fields producing under natural water drive can be classified into two major groups:
- an "edge-water drive" reservoir group in which the water is encroaching from the reservoir periphery, and
- the group of reservoirs in which the oil-sand is entirely underlain by an aquifer.
Reservoirs in the second group are further subclassified as "bottom-water drive" reservoirs and "thin-oil-column" reservoirs. The latter reservoirs are characterized by their relatively equal oil- and water-sand thicknesses and by having both the oil and water zone relatively thin.
When oil is produced from a water-drive reservoir by a partially penetrating well, water breaks through sooner or later before all of the displaceable oil is recovered. Many analyses of this general situation have been made with varying degrees of realism in their approaches, both theoretical and experimental in nature.
Pertaining to the scaled laboratory model studies of natural water drives using porous media, detailed investigations have been made by Henley, et al. on bottom-water drive and by Caudle on edge-water drive reservoirs. No laboratory model studies, however, have been mate to investigate the performance characteristics of thin-oil-column performance characteristics of thin-oil-column reservoirs.
This paper presents the results of a study on scaled model of thin-oil-column reservoirs, operated under varying conditions corresponding to the actual field practices.
The Chemical Logging of Drilling Fluids
Authors: Hughes T. L. , Jones T. G. J. , Geehan Thomas 
Published: December 2007

SummaryA new method of measuring the concentration of ions in water-based mud filtrates is described. The method, based on ion chromatography (IC), provides a tool to monitor changes in the composition of both major ions (sodium, potassium, calcium, magnesium, chloride, sulfate, and carbonate) and environmentally sensitive ions (e.g., chromium and mercury) in mud filtrate during drilling. Changes in filtrate composition are caused by mud treatment and/or mud/rock interactions; chemical logs can be used to discriminate broad lithological changes. The mud-filtrate composition is modeled with a computer-based equilibrium model. The chemical-logging method has been applied to two case studies, one of which involved operation of equipment at the rigsite. The method can be used to monitor the composition of ions not currently analyzed by the widely accepted American Petroleum Inst. (API) Standard 13B-1 procedures.
Through-Tubing Sand-Control Techniques Reduce Completion Costs
Authors: Restarick H. I. , Fowler S. H. , Sedotal W. P. 
Published: December 2007

Summary
Sand-control problems in existing wells typically result from improper completion techniques or changes in reservoir properties. While re-completion of many of these wells with conventional sand-control methods and workover rigs is economically unfeasible, enhance-ments to gravel-pack fluid systems, downhole equipment, and service capabilities have increased success and reduced costs in through-tubing recompletions, providing new options to the operator for successful sand control in existing wells.
Design of an Emergency Response Center
Authors: Phillips Malcolm 
Published: December 2007

Summary
This paper describes the design of BP Exploration's Emergency Centre in Aberdeen. It reviews human factors considered to reduce stress, room functionality, communications, and information technology. It also describes the working emergency-response organization.

Introduction
BP first established a room dedicated to emergency response in 1976, following a fatal accident involving a helicopter in the Forties oil field. People dealing with the accident felt the direct impact of the media for People dealing with the accident felt the direct impact of the media for the first time. The main telephone switchboard rapidly became saturated with calls, making it extremely difficult to summon emergency support. Many key lessons were learned from that accident; the first was the need for a room dedicated to emergency response. So BP built and equipped a new room in its operation control center, which became known as the Emergency Control Room. An adjacent equipment room housed a telephone exchange that was independent of the company's telephone exchange, which facilitated group calls and direct communication with the company's offshore installations.
The accident also showed how important it is to record as much information as possible during an emergency.
Previous experience showed the need for a team with disparate skills during Previous experience showed the need for a team with disparate skills during emergencies. The wide variety of emergencies possible in the North Sea requires a multidiscipline team on permanent standby. The initial call broadcast to this team failed because of technical problems at a local paging company. A paging service under our direct control resolved the paging company. A paging service under our direct control resolved the problem. problem. The way that teams react during emergencies varies. Delayed actions or messages can cost lives. A system of checklists, known as "Prompt," can resolve this problem. Prompt provides a checklist for team activities; individual prompts also exist for each team member.
Prompt initially consisted of a sequence of 35-mm color slides controlled Prompt initially consisted of a sequence of 35-mm color slides controlled from a numeric key pad by the manager. A large central screen displayed actions that the team needed to complete during an emergency.
An emergency coordinator regularly updated slides after accidents and exercises to give feedback on any lessons learned. However, this process could take 3 weeks. A computerized Prompt allows system update within minutes.
The new Emergency Response Centre meets several requirements.A room dedicated to emergencies.Separate installation of equipment and facilities.A multidiscipline response team on permanent standby.A call-out service.Team communication facilities.Prepared checklists.Emergency records.Examination of team performance after an accident.An emergency coordinator.Up-to-date information.
Building Multidisciplinary Business Teams
Authors: Dyson C.J. , Winter N.C. 
Published: December 2007

Summary
This paper describes an approach to managing E&P assets through the operation of multidisciplinary business teams (MBT's). This approach can result in improved asset performance in terms of efficiency, motivation, and business results compared with more traditional matrix-style hierarchies. This paper also outlines certain critical success factors for the long-term success of MBT's and discusses some of the risks of MBT operation.

Introduction
Optimal development of E&P assets is often encumbered by the organizational structure and internal workings of the company(s) owning the assets. All too frequently, the management hierarchies of E and P companies are ill-equipped to focus on the range and diversity of opportunities offered to them in their asset base. This occurs primarily because the authority to make decisions frequently is several levels removed from the source of technical knowledge and the individuals in the best position to make decisions. Thus, people in a position to recognize opportunities to build value into a set of assets often face both communication difficulties and internal competition in persuading senior management to take positive action. Compare this with a situation where all the professional input needed for the enhancement of a given set of assets is incorporated into one core team, and this core team is vested with total management responsibility. This is the essence of the MBT philosophy.

What Are MBT's?
MBT's are groups of staff brought together to manage a defined set of resources. The types of resources or "assets" that are best managed by an MBT are those that are capable of being run as a stand-alone business; that have a defineable value, in terms of both book value and/or market value; and that can be enhanced through value-adding activities. The key assets of an E and P company are licenses for exploration and/or operation. Most licenses fulfill all the above criteria of suitability for MBT management. It is helpful to think of types of E and P licenses as distinct asset types: production assets, production assets under development, and exploration assets. These asset types can be run on a stand-alone business basis and have a value that can be enhanced. The processes of adding value will differ for processes of adding value will differ for producing acreage compared with wildcat acreage. Nonetheless, all can, individually or jointly, constitute the basis of an independent business unit.
Group Unified Accident Reporting Database
Authors: Koene W. , Waterfall K. W. 
Published: December 2007

Abstract
Significant advances have been made recently in enhancing the standard of safety within Shell companies. Safety has been raised to a status equal to other primary business objectives. It is widely accepted that accident prevention is part of good business practice and that a safe operation normally is an efficient operation. Safety programs are being widely implemented that involve all employees, from top management to the contract staff, and the benefits are being realized.
The effectiveness of any safety program, however, must be monitored continuously. Injury and accident statistics play an important role as a prime indicator of safety performance. Statistics form part of the safety management process, indicating the success of the safety programs being implemented and highlighting areas of weakness.
Statistical information relating to the number and frequency of accidents, significant as it is, tells us little about how the accidents occur or about how to improve the intrinsic safety of the operations. More detailed information on accident causes and lessons derived from the investigation of noninjurious accidents and near-hits are required for this analysis and for the setting of appropriate remedial actions.