bluuebunny/crossref_metadata_2025_split huggingface dataset:
Determination of Permafrost Thawing Around Oil Wells
Authors: Sengul M. M. , Brigham W. E. 
Published: December 2007

Abstract
A practical procedure is presented for determining the radius of the thawed-permafrost region around a well and finding the temperature distribution in that region. Such information is important in drilling, completion, and production operations in Arctic regions.
A new numerical method was developed and used in a computer model to generate solutions for radial thawing of permafrost with axial symmetry, which was shown to be a function of three dimensionless parameters plus dimensionless radius and time. The model generated solutions for the range of values of the three parameters for conditions in Alaska's North Slope.
The dimensionless radius of the thawed-permafrost region was related to dimensionless time through a simple power-law equation containing two constants. Results generated by the computer model were used to develop correlations giving the relationships between the two constants and the three parameters. The correlations can be used to find the thawed-permafrost radius, and once this information is available, the temperature distribution in the thawed region can also be calculated.
For the correlations, the temperature at the well was assumed to be constant. In more realistic situations in which well temperature varies with time, we also describe a simple method of calculating the amount of thawing.
Development of High Temperature Electric Submersible Pump
Authors: Pascual Will , Crumley Al , Nelson Chuck , Brady Joseph 
Published: December 2007

ABSTRACT
Todays oil well production is exposing artificial lift equipment to higher and higher downhole operating temperatures as a result of deeper wells and enhanced recovery methods such as steam floods and in situ combustion. KOBE is pursuing a development program that will result in an ESP capable of operation in these high temperature applications. Tests under simulated well conditions of 350°F continuous service are being conducted and have already resulted in design and material developments that make this operation practical. This paper reports on the progress achieved and future testing that is to be done.
Advances in Diver Alternative Systems
Authors: Hawkes G. S. 
Published: December 2007

ABSTRACT
The basic design and selection of oil rig equipment offshore is greatly influenced by the ability to maintain and service such equipment as and when required. A critical analysis of underwater work systems was made and primary research and development conducted that has resulted in advanced new diver alternative systems. Two new systems, a one person one atmosphere microsubmersible, DEEP ROVER, and a robotic device, RIG ROVER, both equipped with newly developed sensory manipulator systems are described. These systems markedly improve work capability subsea and may influence future offshore developments, particularly in deep water.
Interpretation of Some Wireline Logs in Geothermal Fields of the Imperial Valley, California
Authors: Ershaghi Iraj , Abdassah Doddy 
Published: December 2007

ABSTRACT
This study reviews the wireline log responses of some geothermal fields in the Imperial Valley, California. The fields under study include the Heber, the East Mesa, the Brawley and the Westmoreland. The well logs used in the study did not include all the wireline surveys obtained by the operators. The selected well logs obtained under special arrangements with the operators were chosen to maintain the anonymity of specific well locations but are only representative of each area.
Analysis of the well logs indicate that on an individual field basis, the well logs are excellent for correlation purposes. The presence of extremely saline fluids in some fields precludes the monitoring of Qv profile for detection of hydrothermally altered zones. The producing sections in all the fields are characterized by low porosity and high resistivity.
Solid Waste Problems in Geothermal Operations
Authors: Vetter O. J. 
Published: December 2007

Abstract
The solid waste generated in geothermal operations is not limited to silica as often assumed. The silica by itself does not cause unsurmountable solid waste problems. However, numerous other solids coprecipitating with the silica cause major problems in many high temperature liquid-dominated fields.
Depending upon (a) reservoir temperature, (b) reservoir fluid composition, (c) thermodynamics of steam and gas flashing, (d) types of flash and brine treatment facilities and, finally, (e) field operating conditions numerous other solids can be formed at various locations within the field and power plant. Thus, there exists a rather complex relation between the various field parameters and the types and amounts of the various solids.
Solid waste disposal and/or utilization problems are further complicated by the relationships between the formation of scale, i.e., solid deposits adhering to the hardware, and suspended solids to be removed in the various brine treatment facilities prior to reinjection of the heat-depleted brine.
All these complex relationships are explained in this paper by using the rough data from the MCR Mercer 2 field experiments published by DOE/DGE in 1981 and 1982. Approximately 2000 lbs. of a solid, rather impure iron hydroxychloride plus numerous other solid metal compounds are formed from the fluids per well and day.
If these solids are comingled with substantial amounts of amorphous silica, a rather severe waste disposal and/or solid utilization problem becomes evident. At present, this set of problems seems to be the major hurdle for the development of numerous fields.
The technical, economical and environmental problems regarding waste utilization and/or waste disposal are described. Solutions to these problems are far from being available. It is judged that presently developed processes will not solve the rather evident solid waste problems. The only alternative seems to be a combination of mineral recovery and waste disposal processes. This also hampered by numerous technical, economical and environmental problems as shown in the paper.
Analysis of Pressure Pulses Resulting from Magmatic Activity in the Vicinity of Geothermal Wells
Authors: Sigurdsson Omar , Tiab Djebbar 
Published: December 2007

Abstract
The Krafla geothermal field is located in northeastern Iceland. In December 1975 a rifting episode started in the fissure swarm intersecting the geothermal field. Volcanic activity has been associated with the rifting events. During these events pressure pulses have been recorded in nearby wells.
A model based on simple equations describing heat flow in porous media and the pressure diffusivity equation is developed to analyze these pulses. The model is applied to two field cases. The results obtained for transmissivity and formation storage are in good agreement with results obtained from independent well tests.
Rocky Mountain Low Colloidal Oil Mud Applications
Authors: Vesely D. P. 
Published: December 2007

ABSTRACT
Since the advent of low colloidal oil muds in the middle 70s, the system has been tried at several locations in the Rocky Mountains. The system has been used in nearly all basins with mixed results, but in general has proven to be a good choice for deep wells. This paper details the criteria for selecting a low colloidal oil mud over other mud types and documents known areas where the system was successful. In addition, guidelines are presented for estimating cost, along with recommendations for additional equipment and hook-ups required for conserving oil mud.
Fracture Stimulation Treatment of a Western Tight Sand Reservoir: A Case History
Authors: Greenfield H. S. , Ahmed Usman 
Published: December 2007

ABSTRACT
State-of-the-art technology in rock mechanics, fracture mechanics, reservoir engineering and formation evaluation was effectively applied to enhance gas production from a tight gas sand field in Sublette County, Wyoming. Previous attempts at production from this field were not successful due to low initial flow rates and rapid production declines mostly associated with low permeability of the formation. Two research wells were drilled to 12,000 foot depths and a systematic approach towards their completion by hydraulic fracturing was taken by means of associated laboratory, field, and analytic tasks. Laboratory tests on core materials were carried out at appropriate in-situ conditions which resulted in the use of suitable fracturing fluids that caused minimum damage to the matrix permeability and fracture conductivity. Water-base fracturing fluids with high pH (≃8.0) values were recommended for the sand zones investigated. In-situ stress measurements were also taken in and around the selected pay zones. Proper and cost effective proppants were used and strict quality control procedures were imposed during the stimulations.
One zone in each well was successfully fractured. Prestimulation initial production of 107 MCFD for the first well was increased to a post-stimulation value of 4,150 MCFD while the second well was increased from 35 MCFD to 1,450 MCFD. Long-term deliverability projections were made by history matching post-stimulation production and build-up test data.
Presently, the obtaining of ten months of continuous production data from the two research wells is ongoing. A unique trucking procedure to transport the produced gas to a somewhat distant transmission line is emphasized in this case history discussion.
Use of Continuous Coil Tubing for Subsurface Scale and Corrosion Treating—Rangely Weber Sand Unit
Authors: Cruise D. S. , Davis D. L. , Elliott R. H. 
Published: December 2007

ABSTRACT
The deposition of calcium carbonate and/or barium sulfate scale on submersible pumps is the most serious production problem in the Rangely Weber Sand Unit. The conventional method of flushing scale and corrosion inhibitors continuously down the annulus is effective from the pump intake up, but offers no protection to the seal and motor. In an effort to protect the entire pump assembly, Chevron U.S.A. Inc. (CUSA) banded a string of 3/4″ continuous coil tubing to the outside of the production tubing along with the power cable so that chemicals could be injected below the pump. The original installation was a success, and at present there are approximately 30 such installations in Rangely.
Troubleshooting Mature Waterfloods
Authors: Robinson K 
Published: December 2007

ABSTRACT
There has been quite a number of informative papers published recently describing seawater-injection facilities for fields such as B.P.'s Forties (Ref. 1) and Chevron's Ninian (Ref. 2) in the North Sea and GUPCO's El Morgan in the Gulf of Suez (Ref. 3). Those waterfloods described were for relatively new developments, with reservoir permeabilities varying from 100-2,000 millidarcies. They are generally recognised as being successful floods, although each author notes various operating problems caused, for example by corrosion, scale formation and bacterial fouling.
This paper attempts to provide a logical approach to identifying the essential causes of operating problems encountered in a waterflood. These problems can have a dramatic effect on the economics of oil production, particularly for older floods and with tighter formations, where permeabilities may be around 1‒10 millidarcies or less.
Before discussing troubleshooting specifically, consideration is first given to the effects which lead to recognition that there is an operating problem. Waterfloods which use seawater tend to be most common, and have the highest flowrate. However, the following comments are just as appropriate to waterfloods using produced, aquifer or fresh surface waters. The problems may be classified into five groups
Choice and Application of Motion Compensation Systems (MCS)
Authors: Manesse J P 
Published: December 2007

Abstract

DEFINITION OF AN MCS
We will define the MCS in the following way:
System allowing:
– either to transfer a load – or to maintain a connection
between a fixed-support (bottom-supported unit) and a floating support.
This definition can also be extended to immobilisation into space (generally sea water) of a load suspended to a floating support.
We will remind you also of the difference between active and passive systems, due to the fact that it is an essential difference for MCS.
– a system is called passive when it is submitted to external actions and its reactions are only a function of its own characteristics. – an active system receives energy in order to counterbalance external actions. A data-acquisition system of the relative movements floating support/fixed support must be provided.

CHOICE OF MCS

Selection Chart
We have designed a selection chart for MCS clients (see Fig. 1). To be effective, it is very important that the problem be well described and understood.
Solutions for an MCS problem must be adapted since a universal solution does not exist.
The selection chart is composed of different levels to be crossed step by step:
– relative position of the handler and the handled – required function – different technical selection criteria allowing a first approach of the chosen active/passive system. (These criteria are information guide-lines only.) – handling system of the load on the handler – technical solution that we illustrate by a sketch or a reference to an existing leaflet, (see Fig. 2 – Design of solutions)
A North Sea Template Well Tieback System: Design and Operational Experience
Authors: Ingram G W , Humphrey B 
Published: December 2007

Abstract
The North West Hutton field is located in Block 211/27 of the UK sector of the North Sea. It is 80 miles north east of the Shetland Islands, in 473' of water. The field was discovered in 1974. Amoco (U.K.) Exploration Company is operator on behalf of British Gas North Sea Oil Holdings Limited, Amerada Petroleum Corporation of the United Kingdom Limited, Texas Eastern North Sea Inc. and Mobil North Sea Oil Limited.
Development of the field began in 1979 with the installation of a subsea template to allow subsequent early production. The 20-slot template was of unitised construction and was installed and piled in place from the semi-submersible drilling rig Dixilyn Field 96. The DF 96 subsequently drilled seven development wells over a 20-month period and also set bumper piles adjacent to the template. The 60" bumper piles were used to locate the jacket over the template when it was installed in September 1982 followed by hookup and commissioning, tieback and completion of the development wells and first oil in April 1983.
The platform has 40 well slots on an 8 × 5 pattern. It supports two drilling rigs, each serving a 20-slot wellhead bay. Priority was given to the completion and commissioning of the east rig, which covers the 20 slots of the platform which are matched to those of the template. Tieback operations and some completion work were then carried out in advance of production-train commissioning. Accordingly, three wells had been completed and were awaiting perforation on 1 April, 1983, when the platform was certified for production. When all seven are completed the tieback wells should be able to supply the platform's design production rate of 100,000 bopd.
The Petroleum Engineer's Professional Responsibility
Authors: Hickman T. Scott , Mistrot G. A. , Wines G. Bing 
Published: December 2007

ABSTRACT
Because a majority of petroleum engineers fall under the industrial exemption, registration is usually taken for granted as a procedure that is always available if needed. Even registered engineers in public practice tend to view it as a governmental requirement without relating registration to their status as a professional and their responsibility to the public's health, safety and welfare. Professional registration is not exempt from the winds of change originating in our increasingly consumer-oriented, environmenţly-conscious society. Although petroleum engineering has been a well established discipline for over fifty years, it is classified as a "minor" discipline because of the number of licensed practitioners. The increase in the number of recognized minor engineering disciplines in the last two decades has led to proposed revisions in the registering process. Lacking a well developed professional image, petroleum engineering is vulnerable to these proposed changes. Recently, two states proposed revisions that would make it more difficult to register as a petroleum engineer. Periodically, industrial exemptions come under question. These are few of the current issues that pose a possible threat to registering as a petroleum engineer.
The practice of engineering is not a natural or constitutional right. The separate states have the authority to determine who is qualified to practice as an engineer. If the majority of petroleum engineers are content to earn a paycheck and achieve passable competency in a limited area with little regard for the broader aspects of professionalism, we may lack sufficient credibility as a discipline to control our destiny.
Comparison of WAG and Continuous Enriched-Gas Injection as Miscible Processes in Sadlerochit Core
Authors: Spence A. P. , Ostrander J. F. 
Published: December 2007

ABSTRACT
Short core displacements were conducted to evaluate miscible condensing-gas drive for the Sadlerochit reservoir of the Prudhoe Bay field. The cores were from well DS 14-5. The enriched gas was a 60-40 blend on a mole basis of rich Sadlerochit gas and the liquids from the Field Fuel Gas Unit (FFGU) and the separators at Flow Station 3. The experimental program consisted of four floods conducted in each of four cores for a total of sixteen displacements. Each set of floods consisted of: a gravity-stabilized continuous gas injection displacement with the core at connate water saturation;a gravity-stabilized continuous gas injection displacement with the core at waterflood residual oil saturation;a simultaneous injection brine enrichedgas flood at a 4 to 1 brine-to-gas ratio (as determined at reservoir conditions) with the core at connate water saturation;a simultaneous injection brine enrichedgas flood at a 4 to 1 brine-to-gas ratio with the core at waterflood residual oil saturation.
All displacements yielded approximately the same residual oil saturation averaging 2.26% STPV (i.e., stock tank pore volume). The range of values was 0.88 to 3.74% STPV.
The gravity stabilized displacements were piston-like, consistent with the experimental design. The piston-like displacement coupled with the high recoveries indicated rock pore structure did not adversely affect the displacement.
In the simultaneous injection displacements with brine, the oil production was dispersed due to the high fractional flow of brine. However, mobile brine did not affect the ultimate recovery. Trapping or bypassing of oil was not observed. Trapping was observed in a simultaneous injection displacement conducted in strongly water-wet Berea using the same fluids at a 4 to 1 brine-to-enriched-gas ratio. For this flood, the residual oil saturation was 19.4% STPV.
Oil production curves for the simultaneous injection displacements before and after waterflooding were identical except for the early production of the waterflood oil saturation in the non-waterflooded cores. Thus for this linear system, the timing of oil recovery is better for the WAG (i.e., water-alternating-gas ) process operated in the secondary mode as opposed to the tertiary mode.
Interference Analysis of an Anisotropic Reservoir Using Five-Spot Data
Authors: Chen H. G. , Lescarboura J. A. 
Published: December 2007

ABSTRACT
A CO2 miscible flood is being studied in the San Andres 9th Massive formation of the Maljamar Field in New Mexico with a five-acre inverted five-spot pilot. Single-well tests in the five pattern wells and a production interference test with the center well as source and the four corner wells as observers were run to characterize the reservoir prior to the start of the pilot test.
The results of the analyses indicate that the reservoir is anisotropic with the two principal kh's approximately 3,000 and 30 md-ft, and the direction of maximum permeability 77° west of north. The large difference in major and minor axis flow capacities led to a postulate of natural fractures, oriented toward the direction determined by the interference test. The results of the single-well tests reflect the fracture density in their radius of investigation. The proposed reservoir description is consistent with core data and currently available tracer results.
Salem Unit Micellar/Polymer Project
Authors: Ware J. W. 
Published: December 2007

ABSTRACT
Texaco, as operator of the Salem Unit, Marion County, Illinois, is conducting a 60 acre semi-commercial tertiary recovery project in the watered out Benoist sandstone. This paper discusses field design and implementation of the project as well as results to date. An extensive field testing program preceeded initial injection.
The process used is the Texaco developed brine tolerant surfactant system followed by a biopolymer. Application of this process field-wide in the Benoist reservoir at Salem is anticipated to have a tertiary oil target of 50 million barrels. The project demonstrates a process which extends greatly the reservoir salinity range for which surfactant systems have application.
The surfactant system was successful in mobilizing waterflood residual oil. More importantly, the project demonstrates the capability of designing surfactant systems for use in high brine reservoirs without expensive time consuming pre-flushing or reservoir pre-treatment. Field results indicate problem areas to be: Contacting the reservoir with injected fluids (Volumetric Sweep Efficiency), handling and mixing of viscous injectants, treating produced emulsions, obtaining accurate well tests, and bacteria control in biopolymer solutions.
Control of Xanthan-Degrading Organisms in the Loudon Pilot: Approach, Methodology, and Results
Authors: Bragg J. R. , Maruca S. D. , Gale W. W. , Gall L. S. , Wernau W. C. , Beck D. , Goldman I. M. , Laskin A. I. , Naslund L. A. 
Published: December 2007

Abstract
An investigation of loss of mobility control in Exxon's Loudon micellar/polymer pilot test has confirmed that loss was caused by microbial degradation of the xanthan biopolymer used to viscosify the micro-emulsion and polymer drive banks. This paper describes techniques which were used to sample and culture bacteria from the Loudon pilot and demonstrate that these mixed cultures are able to degrade xanthan rapidly under reservoir conditions. Laboratory studies show that, under anaerobic conditions, bacteria cultured from the Loudon pilot can cause over 90% loss of xanthan viscosity in micellar/polymer fluids within seven days.
To remedy this problem, an extensive laboratory screening program was conducted to identify biocides that are effective against the offending organisms. Complete kill of the organisms under repeated laboratory challenge tests was the chief screening criterion. Biocide compatibility (with biopolymer, formation rock, field brines, and microemulsion), cost effectiveness, and chemical stability were also judged key parameters for effectiveness in field applications.
Of the biocides tested against the Loudon organisms, formaldehyde was found to be the most consistently effective, providing complete kill and persistence at levels of 500 to 2000 ppm. Formaldehyde was shown to reduce bacteria below detectable levels in the formation and permit propagation of xanthan in a follow-up test conducted within the highly contaminated pilot zone. Therefore, formaldehyde should be an effective biocide for future floods at Loudon.