bluuebunny/crossref_metadata_2025_split huggingface dataset:
Foam Recompletion of High-Angle, Low-Pressure Dry Gas Wells, Offshore Louisiana
Authors: Pardo C. W. , Andrus T. S. , Bibb B. E. , Bibb S. E. 
Published: December 2007

ABSTRACT
Planning and executing recompletions in low pressure reservoirs (less than 4 lbm/gal equivalent) present operators with several challenging conditions. These include the necessity to protect against formation damage and fluid loss when using low density brines and well control when using foam as the completion fluid.
Low density brines can be effectively used for workover operations in wells to be recompleted in a low pressure reservoir. However, because of the overbalanced condition that exists during workover operations, fluid loss must be controlled by spotting lost circulation pills. These pills can contribute to formation damage and can also affect the gravel placement unless they are effectively removed during the workover operation. In contrast, the formation can be more effectively protected by taking advantage of the low fluid leak-off characteristics and near-balanced pressure when a foam system of the required quality is used as the workover fluid.
A workover program using foam as the workover fluid on wells completed in a low pressure, dry gas reservoir (3.5 lbm/gal equivalent) was conducted offshore Louisiana. This program included cleaning sand from the tubing and/or casing below the packer, reperforating and gravel packing. A conventional foam system was used for cleaning the sand, and a stable foam system was used for well control. The gravel placement was accomplished with a Xanthan polymer system.
This paper will summarize the operational aspects related to the use of foam, the gravel packing operations and the production results after recompletion.
Onsite Design, Analysis, and Automation Maximizes Efficiency of Fracturing Operations
Authors: Van Domelen M. L. , Jantz E. L. , Murphy K. S. 
Published: December 2007

ABSTRACT
Recent advances in onsite data acquisition and automation of field equipment have led to the development of a new fracturing treatment control center. This mobile control center combines design, monitoring, and analysis capabilities with the ability to automatically and remotely control, from within the same unit, all of the fracturing equipment on location.
By using a computer system with increased processing power, and a sophisticated data communications network, many new capabilities are provided:
All fracturing equipment on location can be monitored and/or controlled from inside the control center using a variety of operator interface screens. Set points are sent from the control center to each piece of equipment through a single communications line. More than 1200 measured and/or calculated job parameters, ranging from blender suction pressure to fracture geometry predictions, can be displayed on color monitors during the job. All data are stored internally and can be accessed at any time. Commonly used mainframe computer programs have been downloaded into the control center and can be executed in a background environment. This provides for analysis, design and, if necessary, redesign capabilities while the job is in progress.
This paper describes the system and presents field case histories to illustrate the practical use of the increased computing power and automatic and remote controls now available to help improve the efficiency of the fracturing treatment.
Pressure Buildup Behavior of Partially Completed Wells in Layered Reservoirs
Authors: Olarewaju J. , Lee W. J. 
Published: December 2007

ABSTRACT
This paper presents a study of pressure buildup behavior of partially completed wells intercepting layered reservoirs. We present correlations for estimating skin due to partial penetration for homogeneous and layered systems with contrasting layer permeabilities. We demonstrate the correct procedure for analyzing buildup tests from partially completed wells using conventional type curve analysis methods.
Using an automatic history matching approach, we present a field example application of the analytical model and the developed correlations.
Granular Diverting Agents Selection, Design, and Performance
Authors: Nitters G. , Davies D. R. 
Published: December 2007

ABSTRACT
One of the main problems in chemical treatments concerns the proper placement of the treatment fluids. Specifically, a very distorted inflow pattern may result after stimulation by matrix acidising treatments carried out without a means to distribute the injected fluids over the entire zone to be produced.
A theoretical and experimental study is reported aimed at developing a better understanding of the diversion process. This has resulted in practical guidelines for the application of chemical diverters in general and, in particular, for the use of benzoic acid and its derivatives.
The results of the current study also indicated some areas of uncertainties requiring further investigation.
It is concluded that benzoic acid can successfully be applied in matrix acid treatments in water injectors and gas wells.
Relating Water Quality and Formation Permeability to Loss of Injectivity
Authors: Pautz J. F. , Crocker M. E. , Walton C. G. 
Published: December 2007

ABSTRACT
Water quality is an important consideration in the design of a cost-effective reservoir maintenance or secondary oil recovery project. Proper filtration equipment selection often is not based on scientific facts since knowledge of the formation may be unavailable. Rules-of-thumb that relate size of particulate in injection water to potential permeability reduction have been developed and are used for selection of proper filtration equipment. However, laboratory procedures have not been rigorously applied to the 1/3 and 1/7 rules-of-thumb currently being used to specify water filtration equipment design.
This evaluation of the 1/3 and 1/7 rules-of-thumb used three different core types: Berea sandstone, Cottage Grove sandstone, and a synthetic core. The results showed that rules-of-thumb based on permeability and contaminant particle size are useful in selecting filtration equipment. Results indicated that loss of permeability (core damage) during coreflooding was more severe than expected when the 1/3 rule-of-thumb was used, but not severe enough to consider application of the more stringent 1/7 rule-of-thumb. These two competing rules appear to bracket a reasonable range for water quality.
A model used to relate the amount of oil production to loss of injectivity confirmed these results by indicating reasonable oil production using the 1/3 rule-of-thumb with slightly improved production using the 1/7 rule-of-thumb.
An Investigation Into Practical Removal of Downhole Paraffin by Thermal Methods and Chemical Solvents
Authors: Straub T. J. , Autry S. W. , King G. E. 
Published: December 2007

ABSTRACTOne of the most recurrent problem in the oilfield is the removal of paraffin deposited on downhole equipment and near-wellbore. Several field experiments were conducted to evaluate the effect of hot oiling for either the removal or redeposition of paraffin downhole. Laboratory work is presented that suggests the use of hot solvents has the greatest potential benefit. Means of conventional field application are limited, and nonconventional means are discussed.
Prediction of Downhole Temperatures Can Be Key for Optimal Wellbore Design
Authors: Mitchell R. F. , Wedelich III H. F. 
Published: December 2007

ABSTRACT
This paper describes an advanced method to predict downhole temperatures during operations. Examples are presented that represent actual field cases and demonstrate the advantages of using the advanced method compared to conventional methods of estimating downhole temperatures.
Two specific field cases are investigated in detail: Tubing movement during stimulation and well deliverability. In the stimulation case, comparison of the conventional and advanced methods indicates that 35% fewer packer seals are needed in the specific well studied, and the thermal loads magnify the casing stresses by 25-35%. The well deliverability predictions show that a smaller tubing size increases gas production for a constant surface pressure.
The paper also presents the key engineering and computing features needed to aid engineers in evaluating and interpreting results predicted with the advanced method. Key variables are identified for the different applications. With the model, variables can be controlled to optimize performance of well components and well operations.
The Valuation of Oil Reserves
Authors: Adelman M. A. , Koehn M. F. , de Silva H. 
Published: December 2007

ABSTRACT
The decision to make investments in oil or gas reserves is determined by the relationship between the value of a barrel in-ground and the cost of creating a new one. Wide disparities between these two values will result in investment or disinvestment until the in ground value is equal to the cost of replacement.
Over the past few years there have been several mergers and acquisitions in the domestic oil and gas industry. Some of these mergers have include the purchase of large quantities of proven reserves at prices that were deemed to be low in relation to the development cost of the reserves. This is evidenced in the oft-repeated saying that "it is cheaper to buy oil on Wall Street than by drilling". If so, the price of the asset oil in the ground is much less than its cost. It is difficult to see why sellers insist on giving away assets, year after year. The implication is that the capital market is inefficient, a proposition worth testing. In this paper we examine the market value of reserves to test this proposition.
Oil Supply and Demand Analysis: A Price Forecast for the Post-Iran-Iraq War Period
Authors: Zaid A. M. , Whitman D. L. 
Published: December 2007

ABSTRACT
There is great uncertainty about the supply and demand and price of petroleum products. The semi-free market environment that existed prior to 1973 has long since disappeared. The political and economic situation of the world is becoming even more complex and unpredictable, resulting in greater uncertainties in commodity prices in general and petroleum products in particular. In the last two years we have seen wild fluctuations in oil prices that ranged anywhere between $30 per barrel to $9 per barrel. These sharp cycles in prices have made it virtually impossible to predict the next price cycle, which makes forecasting future exploration, drilling and production almost a futile excerise.
The prospect of a ceasefire between Iran and Iraq has pushed oil futures higher due to the belief that such a ceasefire would lead to greater cooperation within OPEC. The contention that the oil prices would increase as a result of the ceasefire is speculative in nature and does not take into consideration factors such as production history, reserves and a possible economic slowdown in the Western economies following the present expansion.
In this paper, production and reserve figures were examined for OPEC in general and Iran-Iraq in particular. Based on these figures, a production rate was forecasted for OPEC which was added to the non-OPEC production. The combined rate was matched with calculated future demand figures based on the forecasted growth rate in the Western and other economies.
Knowning the probable supply and demand, the the study covers the next five years which will possibly be the most turbulent, at least as far as the oil prices are concerned.
It was concluded that oil prices will remain in the 15-18 dollar/barrel range until 1995. After 1995, an upward pressure on prices could develop, but price increases will not be as dramatic as the increases seen in 1973 and 1980.
Protecting Foreign Risks
Authors: Mansbach B. T. 
Published: December 2007

Abstract
With the downturn in the U.S. oil economy, petroleum engineering and service companies are increasingly looking overseas for work. Many of the exciting developments in the petroleum industry are taking place in the developing countries, requiring parties to accept unique foreign risks. These risks can, in many cases, be covered by a small number of private sector political risk insurers and the Overseas Private Investment Corporation ("OPIC"), a U.S. Government agency, which offers political risk insurance and, to a limited extent, financing for American companies with exposures in the developing countries. This paper describes how those risks can be insured.
The Overseas Private Investment Corporation ("OPIC") is a United States Government agency designed to promote the economic development of less-developed nations by assisting United States citizens, corporations and their wholly-owned (95%) foreign subsidiaries in efforts to invest, or develop contractual relationships, in the third world. As a complement to the U.S. Agency for International Development, which finances projects on a government-to-government basis, OPIC's purpose is to facilitate the transfer of U.S. capital, technology and management skills by helping American companies establish a broad variety of projects in Latin America, Africa, the Middle East, the Indian Subcontinent, Asia and parts of Europe (Portugal, Greece, Yugoslavia, Ireland and Northern Ireland). Its political risk insurance and finance programs operate either independently of or in conjunction with the programs of the Export-Import Bank of the United States, the World Bank (including the International Finance Corporation), the regional development banks, foreign government supplier credit and political risk insurance agencies and private political risk insurers throughout the world. While Congress views OPIC as a development agency, corporate America views OPIC as an insurance company and a source of non-recourse (or project) financing.
A Large-Scale Planning and Evaluation Tool for Upstream Oil and Gas Operations
Authors: Blackburn C. R. 
Published: December 2007

Abstract
APEX is a large scale planning and evaluation model which simulates management decision making under a wide range of variation in the external environment. APEX selects projects for each year of a planning period based on recommended decision criteria and annual capital constraints. APEX is used for a wide variety of strategic planning studies, economic analysis problems, gas contract studies, acquisition and divestiture studies and the large scale, detail long range plan for the company with thousands of capital projects.
Closure Stress Profiling and 3D Fracture Simulations of the Staged Field Experiment Well No. 2, Upper Travis Peak Formation, East Texas
Authors: Miglicco T. P. , Moschovidis Z. A. , Veatch R. W. 
Published: December 2007

Abstract
The Staged Field Experiment (SFE) Well No. 2 is the second of four wells funded by the Gas Research Institute (GRI) for the advancement of research in fracturing and completion technology. This tight gas well is located in a lease owned by Amoco, in the North Appleby Field, Nacogdoches County of East Texas. The well is completed in the Travis Peak Formation which is a sequence of sand shale layers found from 8,000 to 10,000 ft. The permeability and porosity average approximately 0.05 to 0.08 md and 5 to 9 %, respectively.
Extensive pre- and post-fracturing tests were conducted by a consortium of academic and industry participants under the direction of a main GRI contractor. These include the stress testing of 25 zones and two mini-fracturing treatments ranging in volumes up to 6550 bbls. This paper derives a closure stress profile and possible variations using these data and related field experience, and simulates the main fracture treatment using a three dimensional fracture simulator. The simulations suggest fracture width reduction (pinching) at the perforations because of the presence of a low stress zone below and unsymmetric fracture height growth.1 Significant fracture height is indicated by both field data analysis and simulations. Fracture treatment design strategy is significantly affected by this occurrence, which suggests changes to common fracture design practices of many operators in the area. The simulations are compared with post-fracturing field data analysis to assess the resulting fracture geometry and the predictive capabilities of the simulations. Fracture design strategies are suggested for the area resulting from the experience gained from the SFE No. 2 well.
Volumetric Sweep Improvement in the Heterogeneous Tyler Sand of Central Montana
Authors: Mack J. C. 
Published: December 2007

ABSTRACT
Waterflooding is a way of life in the Pennsylvanian Tyler formation in Central Montana; but not without problems. The heterogeneous nature of Tyler sandstone causes premature water breakthrough, water recycling, poor aerial and vertical sweep, and low oil recovery.
New technology to address these problems and improve waterflood performance has been implemented in six Tyler reservoirs in the past ten years. Polymers coupled with gelling agents are used to improve vertical conformance and flood efficiency. Much has been learned on how to better flood the Tyler.
This paper: Reviews the engineered oil recovery projects by defining the program, showing performance and evaluating the success of each project.Discusses the volumetric sweep improvement technology used and improvements made.Makes recommendations on "How to Flood the Tyler".
A View of Natural Gas Transportation
Authors: Ferries N. R. 
Published: December 2007

ABSTRACT
The transportation of natural gas has been defined by some as the movement or conveyance of natural gas from the area of production to the market or ultimately the consumer. The subject paper describes the evolution of state and federal regulations imposed on the transportation of natural gas. The paper also discusses in detail the various FERC transportation programs which producers, pipelines, local distribution companies, and brokers can use to transport natural gas to markets throughout the United States. Finally, the paper discusses Chevron's participation in this evolving transportation environment as seen from the largest producer of natural gas.
In conclusion, with the natural gas industry changing its structure for transportation programs so quickly, it is imperative that an understanding of today's transportation programs and regulation be achieved. This paper outlines the structure of transportation regulation as well as develops an understanding for the FERC transportation program available today.
Impact of FERC Orders on Regulation of Gas in New Mexico
Authors: Lyon V. T. 
Published: December 2007

Abstract
FERC Orders 380, 436, 451, 490 and 500 promote competition among suppliers of gas for the benefit of the consumer and provide access to transportation of gas directly from producer to consumer. The "unbundling" of gas services has restructured the interstate pipelines and caused producers either to market their own product or find a broker. The disruption of contracts has upset the producer, pipeline and state regulatory agencies. Setting allowables, reporting gas sales, payment of taxes and royalty, and accounting to non-operating working interests are more difficult to administer and correlative rights are being confused.
The New Mexico Oil Conservation Division has changed some procedures to cope with this rapidly changing situation. More changes will be needed to do our job under the state's Oil and Gas Act. The priority system designed to keep hardship wells producing and casinghead gas flowing is in jeopardy. The State's role in preventing waste and protecting correlative (property) rights must be recognized by Federal agencies.
Improved Safety and Reduced Costs for Gas Piping Maintenance
Authors: Cohen J. H. , Pittard G. T. , Wilkey M. L. 
Published: December 2007

ABSTRACT
REMS is a new system for reducing costs and improving safety of repairing buried utilities. This paper describes the design and operation of the REMS equipment and field test results. In addition to enhancing safety by nondamaging excavation, economic modeling (presented in the paper) shows the equipment can reduce current repair costs by as much as 50 percent through increased productivity and reduced restoration.
Recovery Optimization in a Bottom/Edge Water-Drive Gas Reservoir, Soehlingen Schneverdingen
Authors: Cohen M. F. 
Published: December 2007

Abstract
A reservoir simulation study of a water-drive gas reservoir, the Soehlingen Schneverdingen Sandstone, was carried out in order to estimate its gas in place and to determine production strategies which optimize the ultimate recovery.
The reservoir study was performed with Mobil’s black oil simulator, ALPURS, and followed closely the representation set forth by the log analysts and production geologists, which determined the geologic zonations and many of the reservoir parameters and trends. During the history-match phase, the critical match parameters proved to be the vertical communication and the aquifer size in comparison to the gas-cap size. The vertical communication could be specified from a coning study of a well producing water, and from diverging shut-in pressures which developed between two wells in the field. The aquifer si?e in comparison to the gas-cap size could be determined within limits from the differing pressure developments at the producing wells.
The prediction phase of the study revealed the somewhat surprising result of gas pockets being left behind even by structurally-high wells. This is a consequence of the water front cusping into the wells before the pressure level in the gas zone could be completely reduced. The thin layers of tight vertical permeability also contribute to this effect by reducing communication within the gas cap.
Several alternative production strategies were investigated in detail, such as accelerating the gas production to "outrun" the water encroachment, producing large amounts of water in one well after it waters out to slow the water movement to the other wells, and varying the location and the timing of additional wells. The accelerated production and other timing effects do not appear in this case to provide a significant improvement in the ultimate recovery. Water production, however, would be beneficial under certain circumstances, provided that the water could be economically disposed of. After accounting for the technical feasibilities as seen today, the various management proposals could be evaluated for the future development of the field.
Natural Gas Separation From Arsenic Compounds
Authors: Block-Bolten A. , Glowacki K. 
Published: December 2007

Abstract
Methods of removing arsenic compounds from natural gas and accompanying water to meet environmental requirements are discussed. Purification methods to remove arsine are evaluated and some are given preference. Data about process emissions from existing technologies are adopted. Most interesting patents including pyrolysis, adsorption, and absorption are listed. Potassium permanganate method is chosen as the most appropriate method to remove arsenic compounds from natural gas. Batch process to treat reservoir water and to regenerate the aresenic-saturated solutions and suspensions of potassium permanganate is recommended. The chemistry and thermodynamics of water conditioning process is presented.