bluuebunny/crossref_metadata_2025_split huggingface dataset:
Evaluation of an Anti-Sealant Squeeze Treatment From Pump Run Life and Radiotracer Response in Produced Water
Authors: Suzuki F. , Wood K. N. , Lee G. L. , Bawol D. A. 
Published: December 2007

Abstract
A field test was recently undertaken to investigate the effectiveness of an anti-scalant squeeze treatment. Its overall effectiveness was assessed by pump run life. To gain insight into chemical behaviour, a mixture of carbon-14 tagged organophosphonate anti-scalant and tritiated water was added to the treatment prior to squeezing it into the formation. Treatment flowback was monitored by analyzing produced water samples for radiotracer concentrations.
The treatment successfully extended pump run life to nearly three times its expected value. During the 6.5 month test period, 67 % of the water was recovered as compared with only 16 % of the anti-scalant. This indicates that while the bulk of the treatment was successfully placed in the near well-bore region, most of the anti-scalant chemical stayed in the formation. Squeeze treatment technique and possible mechanisms for chemical retention are discussed. The radiotracer technique is also compared with other methods for anti-scalant analysis.
The Extensional Viscosity Behavior of Polymeric Liquids of Use in EOR
Authors: Walters K. , Jones D. M. 
Published: December 2007

ABSTRACT
The rheometrical behaviour of dilute solutions of a high molecular weight polyacrylamide is described, with particular reference to the dramatically high values of extensional viscosity which are possible. The effect of such factors as polymer concentration, salt concentration and mechanical degradation on rheometrical properties is outlined.
Reference is made to the qualitatively-different rheometrical behaviour experienced by comparable solutions of xanthan gum.
Financing Domestic Natural Gcis Development in the 1990's
Authors: Pollio G. , Marian W. S. 
Published: December 2007

ABSTRACT
Recent analyses of the natural gas market typically ignore the sweeping changes that might be expected to follow from the elimination of the current deliverability surplus. In this paper, we explore the implications of these potential changes, both in terms of their impact on sectoral performance and the willingness of energy finance markets, above all, banks, to fund future natural gas development.
Evaluation of Procedures for Preparing and Sampling Dry-Blended Cements
Authors: Bell D. R. , Nahm J. J. , Dammel T. C. 
Published: December 2007

ABSTRACT
An evaluation of bulk blending and sampling procedures was conducted using cement blends prepared at seven bulk plants located in four different regions of the United States. Blending variables investigated include batch size, number of transfers, and the effect of aeration. Three types of sampling devices were also evaluated: an automatic sampler, a specially modified ball valve sampler, and an improved diverted flow sampler. Three transfers of cement blends from one vessel to another were necessary to obtain a representative blend. Other variables evaluated had little effect on blend uniformity after three transfers. A modified ball valve sampler was safer to use than the ordinary valve type samplers, but the improved diverted flow sampler equipped with air actuators was convenient to use and provided consistent performance.
An Extended Black Oil Miscible Simulator That Rigorously Treats Variable Bubblepoint Problems
Authors: Ammer J. R. , Sams W. N. , Brummert A. C. 
Published: December 2007

ABSTRACT
The extended, black-oil, miscible reservoir simulator MASTER was developed specifically to support the Department of Energy's Enhanced Oil Recovery Program. The implicit-in-pressure, explicit-in-saturation simulator contains mass balance equations for oil, water, natural gas, up to four solvent species, and a surfactant. Several options have been incorporated into MASTER to simulate the phenomena associated with gas miscible flooding: (1) including the loss of solvent to the aqueous phase, (2) choosing the degree that water blocks oil from contacting injected solvent, (3) allowing precipitation of asphaltenes with subsequent permeability reduction, and (4) reducing gas mobility as a function of surfactant concentration. MASTER was validated by comparing predicted results with results presented in the Society of Petroleum Engineers first and fifth comparative solution problems. Results predicted by MASTER compared favorably with SPE's results. Thus, MASTER can be disseminated for public use.
Applications of Nodal Analysis Technique for Appalachian Wells' Production Problem
Authors: Suhy T. E. , Hefner M. H. , Yu J. P. , Mustafa A. 
Published: December 2007

ABSTRACT
A software package has been developed in which a gas simulation model and Nodal analysis model are used in conjunction with fracture simulation. The software package is also tied to a microcomputer database system to provide pertinent data for well analyses. The gas simulation model generates inflow performance for various production conditions while Nodal analysis studies the inflow and outflow conditions. Since specific Appalachian production conditions are used for both models, the software package will prove to be a useful tool for improving production in the Appalachian area.
Artifical lift "rabbit" production, bailing/swabbing operation, restimulation of the new zone and deeper drilling are the conventional methods to improve the production in the Appalachian area. Nodal analysis technique has been used with specific wells to evaluate the potential results of using each recovery enhancement method.
Nodal analysis is an optimization technique to analyze production problems and predict solutions. This technique can predict the "critical" pressure for artificial lift and can predict the inflow performance of a well. The new bailing operation can then be scheduled accordingly. In addition, this technique can also estimate the skin damage within an existing well and be used to justify restimulating the new zone or drilling deeper. In the Appalachian area, tight formations and relatively depleted reservoirs are major problems. The current marginal economic situation does not allow producers to improve production by pressure enhancement and multiple stimulation. A solution can be obtained by analyzing the problem and predicting the outcome of using various production enhancement methods. Then, the operator can select the proper method to use.
Dynamometer Test Results in the Eastern United States
Authors: Rdissi A. 
Published: December 2007

ABSTRACT
Since its introduction to the Eastern United States in the early 1980's when it was received with little enthusiasm, dynamometer testing has become more accepted. Operators and field personnel have become more familiar with its applications and benefits to producing pumping wells. This paper compiles dynamometer card results from several hundred tests conducted in the region during the last few years. A wide spectrum of benefits were derived from the analysis of these tests. The benefits include an evaluation of the performance of all the pumping equipment, the correction of problems outlined by the tests, and the use of test data to design equipment for undeveloped oil fields. The major benefit is the increase in gas and oil production. Because of the tedious calculations involved in interpreting the dynamometer card, a computer program that consists of a few subroutines was written to help the engineer make a precise determination of the problem encountered. Therefore he is able to offer useful recommendations to improve the well's performance.
Production Potential and Strategies for Coalbed Methane in the Central Appalachian Basin
Authors: Kelafant J. R. , Boyer C. M. , Zuber M. D. 
Published: December 2007

ABSTRACT
A regional geologic assessment of the Lower Pennsylvanian age formations in the Central Appalachian Basin has indicated that the coalbeds of the Pocahontas and Lee/New River formations have a high potential for gas production. This study, sponsored by the Gas Research Institute, has established an in-place gas resource estimate of over 5 trillion cubic feet for the six primary coalbeds in the targeted east central portion of the basin. Using a production simulator designed specifically for the unique reservoir characteristics of coalbeds, estimates of gas production under varying geographic and reservoir conditions were made. The many thin, discontinuous coalbeds of the basin suggest that gas production from multiple coal seams within a single wellbore will be the optimal completion technique.
Operational Efficiency Comparison Between a Deepwater Jackup and a Semisubmersible in the Gulf of Mexico
Authors: Childers M. A. 
Published: December 2007

ABSTRACT
A commonly held industry viewpoint is that deep water (WD) jackup ( 250-350 ft plus WD) is the preferred rig type over a shallow water semisubmersible (600-1000 ft WD) from almost any viewpoint including operational, efficiency, cost, risk, and potential rig downtime. A time study was conducted with various operational scenarios that show from the time a jackup/semisubmersible starts to move on location to drill out of surface casing the semisubmersible (SEMI) should on average perform the operation in 1.8 to over 4.7 days faster than a deep water jackup. Also for the permanent well abandonment to moving off location, the SEMI on average will be able to accomplish the same in 0.6 to 1.5 plus days faster than a deep water jackup. Summing the start and finish operations for the well, the SEMI on average assuming a good, steady, reasonably trouble free operation for both type units should be quicker by 2.4 to 6.2 days. With current contract day rates, and cost of wellheads, casing, rental of BOP, etc., a shallow water SEMI total well cost will generally be less than a deep water jackup.
Mobility and Speed in a Workover/ Completion Rig for the Arctic
Authors: Gardner G. B. , Snisarenko P. P. 
Published: December 2007

ABSTRACT
In April, 1984, ARCO Alaska, Inc. published specifications for a workover/completion rig for the Kuparuk oil fields, located on the North Slope of Alaska. ARCO was seeking a rig which could handle a static hook load of at least 300,000 lbs., with the capability of moving well-to-well within 3 hours and pad-to-pad inside a 5-mile radius within 12 hours.
Nordic-Calista Rig 1, designed specifically for that contract, performed its first day of production on April 4, 1985. Subject rig has, in its entire history of operation, beaten those original move time requirements 100% of the time. From daily production reports of Nordic-Calista Services No. 1, the joint venture owner and operator of subject rig, during the one year period June 1, 1987 to May 31, 1988, well-to-well move time averaged just over 22 minutes and pad-to-pad, up to a 5-mile radius, move time averaged just under 2 hours.
Built on three levels, the unit is completely self-contained, self-propelled with a top speed of approximately 2.5 miles per hour, winterized for harsh Arctic operations, and is capable of performing work-over/completion operations to a depth of 16,000 feet. Rig up and tear down time has been virtually eliminated, except where the unit is required for the Prudhoe Bay oil fields nearby. 45-foot height restrictions there in require removal of the derrick and disassembly of its wind walls in such instances.
Drillstring Design Optimization for High-Angle Wells
Authors: McKown G. K. 
Published: December 2007

ABSTRACT
Drill string design for high angle wells should be optimized for all required functions of the drill string. Optimum drill string design requires a thorough review of well design and objectives in order to rank in importance the demands of a drill string. Practical considerations for drill string design for high angle wells and systematic approaches to the design process are presented.
Benefits, Limitations, and Applicability of Steerable System Drilling
Authors: DeLucia F. V. 
Published: December 2007

ABSTRACT
Advances in on-demand directional control using steerable drilling systems has progressed significantly in recent years. These systems can provide tangible improvements in cost-per-foot and drilling optimization, as well as intangible benefits in wellbore quality and predictable drilling performance.
Results can be quite dramatic when the steerable system is carefully designed and is used in the appropriate drilling situation. While steerable system drilling has the flexibility to perform most directional control tasks required of traditional directional drilling operations, thorough analysis and planning will ensure that the operator achieves maximum economic and performance benefits.
This paper examines system design and operation, performance benefits, proper application and the limitations of steerable drilling system technology.
Hammer Bits Control Deviation in Crooked Hole Country
Authors: Johns R. P. , Witt C. , Frederick M. 
Published: December 2007

ABSTRACT
Air percussion drilling tools, and hammer bits in particular (Figures 1, 2 and 3), are somewhat new to the oilfield. In the last three-to-five years, conventional hammer bits have been utilized in air drilling regions with great success. Hammer bits have increased penetration rates and reduced deviation problems over conventional air rotary drilling, making drilling during the recent downturn of oil and natural gas prices more attractive (1). Figure. 1Hammer bit profile specific features.Figure. 2Hammer bit profile. locking rings & driver sub.Figure. 3Pnuematic air hammer Internal workings.
A new diamond-enhanced hammer bit utilizes polycrystalline diamond technology (2). The hemispherically-shaped tungsten carbide inserts used in the hammer bits have a highly wear- resistance polycrystalline coating (Figure 4). Successful field use of the bit indicates that the tool could be a solution to severe deviation problems encountered in the Appalachian, Arkoma and, Permian Basins. Figure. 4Diamond enhanced Insert cutaway.
The Application of the Drilling Motor
Authors: Schmidt G. J. , Flickinger G. L. 
Published: December 2007

ABSTRACT
Proper application of the DC Drilling Motor to drill rig equipment, including mud pumps, rotary table, top drive and drawworks, is essential in obtaining maximum performance and long life from the motor. Emphasis is placed on taking advantage of the motor's torque and speed characteristics with a variable DC voltage source such as the SCR. Comparison of the advantages and disadvantages of the shunt and series type DC motor are analyzed. Recommendations are given on proper methods of motor cooling, storage, maintenance, troubleshooting and returning the drilling motor to service.
Offshore Drilling Rig Modifications for Deep Well Drilling: A Systematic and Economical Approach
Authors: Snyder D. L. , Childers M. A. 
Published: December 2007

ABSTRACT:
Odeco has upgraded a Victory class semisubmersible and a Bethlehem slot jack-up rig to accommodate the heavy loads associated with drilling wells below 20,000 feet in the Gulf of Mexico. Several world records have been set with these rigs since their upgrades.
This paper will discuss the numerous operational and economic challenges a drilling contractor is faced with in order to strengthen and upgrade a rig for drilling ultra deep wells below 20,000 feet. These include analyzing rig capacities such as drilling equipment, setback, combined substructure, well control, liquid and bulk systems, solids control, deck storage, variable deck and leg loading and power plant. A precise inspection plan must be formulated before and during the well for all of the contractors equipment. Additionally, the entire analysis and upgrade must be done economically and generally in less than 60 days in order to compete in today's marketplace.
While many rigs are capable of drilling deep wells, few rigs can safely accommodate all of the demanding aspects of ultra deep drilling. It is important that the "whole" rig, its equipment, and its operational capability meet all requirements, not just a vast majority of those requirements.
RCRA Subtitle D Application to Drilling Operations
Authors: Freeman B. D. , Collins J. W. 
Published: December 2007

ABSTRACT
The Environmental Protection Agency (EPA) presented the Regulatory Determination on drilling muds, produced water and associated wastes to Congress on June 30,1988. One conclusion was regulatory gaps were present in some State oil and gas programs that compromised environmental protection. EPA believes they have authority under Subtitle D to fill these gaps. However, the Subtitle D type waste management guidelines, as being formulated by EPA to regulate mining operations and municipal landfills, are not viable or cost effective when applied to Oil and Gas Industry (0GI) operations. The existing drilling waste management practices used by the OGI in a number of State oil and gas programs though are viable and cost effective to ensure environmental protection. These existing practices as discussed in this paper can be implemented in applicable State programs to fill regulatory gaps.
Drilling Contracts: Pursuit of an Equitable and Balanced Relationship Between Operators and Contractors
Authors: Moomijan C. A. 
Published: December 2007

ABSTRACT
The steep rise and fall in the demand for drilling rigs during the last decade not only has created the expected swing in rig rates but also has wit-nessed a dramatic shift in commercial terms and allocation of risks in drilling contracts. Although the supply/demand ratio inevitably will control rig rates, the author suggests that the long term interests of Operators and Contractors justify implementation of a rational and standardized ap-proach to achieve equitable contract terms in both weak and strong markets. First and foremost, a drilling contract should be comprehensive, clear and enforceable. Commercial provisions, such as those addressing term extension options, rate structure and termination rights, should be written in a comprehensive fashion to fairly reflect the agreement between the contracting parties and facilitate orderly contract administration. Provi-sions addressing allocation of risks for potential losses and liabilities and the contract clauses detailing insurance requirements should be drawn in consideration of the risks customarily absorbed and insured by Operators and Contractors in order to create a clear demarcation of risks and avoid cost-ly duplication of insurance coverages.
Drilling Contractors Against Drugs: Integrity in the Workplace
Authors: Hopkins B. 
Published: December 2007

Abstract
A drilling contractor's service is his only product. The integrity of this service depends on well maintained and operated equipment and. most importantly, on well trained, knowledgeable, skilled and alert crews.
Drilling contractors are emphatically against drugs and have taken strong actions to enhance and preserve the integrity of their workplaces. Both land and offshore, drilling contractors are striving to eliminate the effects of drug use on their rigs.
Accidents and other operational mishaps represent serious flaws in the quality of service. An analysis of serious accidents indicates that only 10 to 15 percent are caused by equipment or mechanical problems, while 85 to 90 percent are caused by human error. Any and all things that reduce the effects of human error on a drilling rig will improve performance. This is where drilling contractor drug programs are aimed--squarely at reducing human error and increasing safety of personnel, performance of the rig, and quality of service to the customer.
The Cost of Environmental Compliance
Authors: Stewart D. A. , Templet J. D. 
Published: December 2007

ABSTRACT
The objective of this presentation is to summarize the nature and scope of the more major costs of environmental compliance as they apply to the field operations of oil and gas well drilling and production. An analysis of the appropriate federal laws is also addressed and included are the necessary reporting levels in both the federal and state governments. This information should be sufficiently definitive to allow the uninitiated to reference sources and begin a compliance program. Also, the advanced reviewer will not only receive a refresher, but additional insight into potential future jurisdictional arenas that appear to be on the horizon by both federal and state regulatory agencies.
Toxicity and Performance Testing of Non-Oil Spotting Fluid for Differentially Stuck Pipe
Authors: Halliday W. S. , Clapper D. K. 
Published: December 2007

ABSTRACT
Differentially pressured stuck pipe is a serious problem in the Gulf of Mexico and other areas of the world which results in costly and lengthy time delays. For years diesel oil, mineral oil, and mixtures of these oils with surfactants, clays, and asphalts have been spotted to help alleviate differentially pressured stuck pipe. With the advent of the Environmental Protection Agency's National Pollutant Discharge Elimination System (NPDES) General Permit on July 2, 1986 and the ending of the Diesel Pill Monitoring Program (DPMP) on September 30, 1987 the use of these conventional spotting fluids is becoming more stringently controlled in the offshore waters of the United States. In fact, after the use of conventional spotting fluids, the entire mud system may have to be sent ashore for disposal since offshore discharge is not allowed. In an effort to provide an environmentally acceptable alternative to oil based spotting fluids, a laboratory procedure was developed and used to measure the ability of various chemicals to free a metal bob held in a filter cake by a differential pressure. After the effective additives were identified, a few were selected for bioassay. One water-soluble agent, in addition to being highly effective in the stuck pipe simulation test, had a very low order of toxicity. This material was formulated into an experimental spotting fluid that successfully freed a differentially stuck drill string in the Gulf of Mexico.
The development of a non-oil, low toxic spotting fluid has provided a suitable alternative to conventional spotting fluids resulting in an effective and environmentally safe way to combat differential pressure sticking of the drill string.
Underreaming: Old Method with New Technology
Authors: Desai P. C. 
Published: December 2007

ABSTRACT
Underreaming is a highly underrated technology. It has been viewed primarily as an undesirable, yet often inevitable, cost in too many wells or standard methodology in remedial applications. Recent advances in deeper drilling have created the need for multiplecasing strings in straight and directional wells. As a result, the demand for more durable, reliable underreamers has increased. Underreaming allows the operator to run minimum clearance casing programs which optimize casing sizes and reduce tubular costs on multiple-string wells.
The performance of conventional underreamers has been inconsistent due to several inherent problems such as short cutter life, marginal hydraulics and component weaknesses. This paper examines these problems and describes a new, innovative underreamer that incorporates design solutions. Underreaming is discussed as a system which encompasses stabilization and computerized hydraulic analysis in addition to underreaming tools. A summary of field data also is detailed.