bluuebunny/crossref_metadata_2025 huggingface dataset:
A Single Tool for Corrosion and Cement Evaluation
Authors: Dumont Alain , Patin Jean-Bernard , Floch Gilles Le
Published: December 2007

The CET (*) tool was initially designed as a Cement Evaluation Tool, based on the ultrasonic resonance of the casing. This resonance, induced and sensed in a pulse-echo mode, depends on the thickness of the casing, on the medium behind the casing, and is also sensitive to casing wear and corrosion. In addition to the exploitation of the amplitude of the echoes and of its eight high resolution (0.1 mm) calipers, the tool was modified to give eight local steel thickness measurements, 45 degrees apart. Thickness is obtained with a resolution of 0.1 mm (0.004 in.) through the determination of the resonant frequencies of the pipe wall.

The technique has been widely field-tested, in Europe and in North America, and log examples show the ability of this new tool to detect changes of casing weight, distortion, perforation damage, scaling, wear from the drill pipe, corroded zones, acid attack…

This new tool performs the same cement measurements as the CET tool, and has the same size. By providing cement and corrosion evaluation in a single run, it is a unique means of casing investigation.
Constraints on Offshore Exploratory Operations Imposed by California Environmental Regulations
Authors: Pickford K. H.
Published: December 2007

Increasing levels of environmentally-based regulations have introduced significant constraints to exploratory operations conducted in California waters. Specific regulations are intended to protect the coastal environment in the areas of air quality, water quality, fishing and marine resources, and aesthetics. These regulations can affect the method, location, timing and expense of offshore operations, both in monetary terms and in terms of operating restrictions.
Oil Mud Techniques Improve Performance in Deep, Hostile Environment Wells
Authors: Golis S. W.
Published: December 2007

Exxon Company, U.S.A., experienced an average 100% overall penetration rate increase and a resultant 50% drilling intangible cost savings per well on three recent deep, hostile environment wells. Improved invert emulsion oil mud techniques were major factors in this success.

The oil mud program for each well was designed to provide a low viscosity and solids content drilling fluid in the hostile environment. Oil mud usage in the large protective hole intervals improved hydraulic cleaning efficiency and yielded maximum penetration rates. Hematite, a higher specific gravity weighting agent, reduced total solids content and mud viscosity. Decreasing the low gravity solids content also diminished viscosity and eliminated differential pressure sticking incidents. A high oil;water ratio optimized rheo-logical property control. A low filtrate loss reduced mud costs and stuck pipe potential. No penetration rate reduction associated with the low filtrate loss was noted. Sufficient salinity content contributed to optimum bit performance and formation stability.

This paper examines actual field results and develops a correlation between specific mud techniques and increased drilling performance. Recommendations are presented for improved oil mud performance in deep, hostile environment wells.
Interpretation of Results From Well Testing Gas-Condensate Reservoirs: Comparison of Theory and Field Cases
Authors: Behrenbruch P. , Kozma G.
Published: December 2007

A more complete understanding of well test interpretation results for gas-condensate fields may depend significantly on the availability of sufficient, accurate and specific field correlations involving fluid and rock properties, and on flow meter surveys.

Apart from compositional variations, the most useful parameters in reviewing gas-condensate samples are condensate-gas ratio, dewpoint pressure and gas gravity. Pressure data recorded by quartz crystal gauges can result in gas gradients with sufficient accuracy to confirm variations in gas composition with depth for a reservoir of several hundred metres in thickness. By comparing these gradients with gas gravities from fluid samples, variation of the initial dewpoint pressure with depth was established.

Special core analysis was carried out† to obtain specific high velocity β-factors. However, when these laboratory measurements are compared with results obtained from production test analysis, large discrepancies are found in most cases, which can be attributed to multiphase flow near the wellbore. Although wellstream composition is found to be a function of rate, the presence of a stable condensate bank appears to be unfounded.
An Overview of the Installation, Operation, Maintenance, and Problems Associated With Electrical Submersible Pump System in Central Sumatra, Indonesia
Authors: Tabe F. L.
Published: December 2007

P.T. Caltex Pacific Indonesia, operating under a Production Sharing Contract with Pertamina, the State Oil Company of Indonesia, has a production capacity in excess of 750,000 BOPD (119,240m3). The Company's operations are mainly centered in Riau Province in Central Sumatra, an area of virgin tropical rain forests and is relatively quite under developed.

The Company has in excess of 1000 electrical submersible pumping units in operation to provide the major method of artificial lift for its operations. All aspects of the provision of electric power and the installation, operation and maintenance of the electric submersible pumping units are conducted by Company personnel.
Low Cost Wellsite. Determination of Bottomhole Pressure from Acoustic Surveys in High Pressure Wells
Authors: Podio Augusto L. , Weeks Steve G. , McCoy James N.
Published: December 2007

The risk and cost involved in undertaking bottom-hole pressure surveys by wireline in high-pressure gas wells, especially those which produce sour gas, often discourages obtaining information which is vital for evaluation of well performance.

Field tests have verified the accuracy of a sensitive, high-pressure acoustic instrument that enables determination of fluid levels and/or echo-time to a downhole marker, without limitation by depth, well tubulars or environment. This has opened the way for development of a diagnostic technique giving information about well pressures and fluid distribution in the wellbore without the use of downhole pressure survey tools. This Wellsite Pressure Calculation System (WPCS) is especially applicable for hostile environments, attributable to high pressure/high temperature, sour gas production, where wireline surveys involve significant risk and expense.

Results, supported by field tests involving pressure buildups under controlled conditions, indicate the calculated pressures agree with those measured by downhole pressure bombs to within the accuracy of the pressure bombs (1%) and can be used satisfactorily in buildup analysis.

A description of three sets of field tests is given, as well as the development of programs for wellsite data analysis using a portable, battery-powered microcomputer.
Oil Saturation Evaluation for EOR in a Carbonate
Authors: Cannon D. E. , Rossmiller J. W.
Published: December 2007

Two wells in the San Andres dolomite of west Texas were cored and logged to evaluate the residual oil saturation (S or ) for enhanced oil recovery. The log responses of both wells were very similar. One well's conventional core showed an average of 9 percent S or and the o ther well's pressure coreshowed 30 to 40 percent S or . A means of tying the log and core information together was needed where the in-situ S o and formation water resistivity (R w ) values were questionable. Core values of m were chosen as the tie. They were compared to back-calculated m values from various logs to confirm R w and S o . Through-casing gamma spectrometry carbonoxygen values of 1 - S w (S o ) were used to further confirm the final S o . In the iteration process of bringing core and log answers closer together, it was found that the dolomites were very laminated and the dual laterolog data were being adversely affected by shoulder beds. Much of what appeared to be invasion was a shoulder-bed effect. The invasion-corrected value (R t ) was reduced in the permeable zones to 0.7 of the original value when shoulder-bed corrections were made prior to invasion corrections. Detailed core analyses and computer-processed logs were brought into reasonable agreement.
The Operator-Contractor Relationship—Gains and Losses, 1982 to 1984
Authors: Combes J. D.
Published: December 2007

Through the last several years, the petroleum drilling industry has experienced both a boom and a slowdown. This relatively low supply and high demand for rigs in the " boom times" was a contractor's dream. Now the tide has turned, whereby the industry has regressed producing a slowdown. The operator has become more selective in the rig selection process. This selective ness, on the part of the operator, has forced the contractor to become competitive through cost cutting and manpower reductions. How does this effect the drilling industry? Who's to gain? or Who's to lose?…the operator or the contractor?
Construction and Certification of a U.S. Flag Jackup for Norwegian Waters
Authors: Covellone T. C. , Thorson J. A.
Published: December 2007

In 1981 Global Marine Drilling Company contracted for the construction of a large jackup drilling rig capable of year around operation in very severe, relatively shallow water environments, such as in the North Sea and Eastern Canada. This rig was delivered in 1984 and is named the Glomar Moray Firth I. This rig is the first non-Norwegian flag MODU to fully comply with the rules of the Norwegian authorites – generally accepted as being some of the most severe in the world. Integrating the regulatory body requirements of four countries (Norway, United Kingdom, Canada and the United States) and the IMO and SOLAS rules, proved to be a extensive technical and logistical task. The highlights of this effort are addressed in this paper.
Operator Engineered and Maintained Mud Systems: A Way To Reduce Costs and Improve Drilling Efficiency
Authors: Lee L. G. , Bernard H. J.
Published: December 2007

In August 1982, ARCO Oil and Gas Company's South Permian District, in a successful effort to reduce costs and improve the efficiency of drilling operations, began purchasing mud materials without the services of the vendor's mud technician. ARCO's drilling personnel were equipped with API standard mud testing equipment and trained in drilling mud practices. Because of this, the District received lower pricing from vendors and greatly improved mud cost controls. Two main reasons for this policy were these:To reduce drilling costs andTo increase drilling personnel's knowledge of drilling mud design and applications with its relationship to other aspects of drilling.

This paper briefly discusses the success of ARCO Oil and Gas Company's program of operator-engineered and maintained mud systems from August 1982 to August 1984 and compares costs before and after the program was initiated.
Hole Cleaning: Some Field Results
Authors: O'Brien T. B. , Dobson M.
Published: December 2007

When the hole heaves, falls in or is plagued with excessive fill, much time is lost reaming and redrilling. Typically six to ten days of washing and reaming are required to remove cavings if the drill string does not get stuck. This paper will be a report of several field applications of methods used to clean a hole.

Fluid and well equipment conditions required for proper hole cleaning are given as is the basis for their selection.

Hole cleaning problems and solutions in various hole sizes, different types of rocks and different drilling fluids are described. Examples are largely from the Delaware, and Anadarko Basins.

Very severe hole caving problems have been cured in a short time when the proper conditions are met.
The Spiral Flow Cylindrical Mud Mixer
Authors: Stinson D. L. , Underwood G. E.
Published: December 2007

The Spiral Flow Cylindrical Mud Mixer (SPCMM)* is a unique system recently developed for mixing large volumes of mud quickly under controlled conditions. Its streamlined internal shape allows regular flow by minimizing obstructions. A well organized flow pattern from the outside walls of the mixer into the centrally located suction eliminates dead spots and promotes uniform mixing of the contents. Field tests indicate that this system will mix mud approxiamtely four times as fast as other existing systems. The speed of mixing up to this time has been determined by the limitations of adding materials to the mixer, and not the speed of the mixing action of the mixer.

This new system may be applied whenever an operator needs large volumes of mud with carefully controlled properties to solve well control problems. Plant tests have shown that this mixer will produce 214 bbl. of 17+ lb/gal. mud in a 24 hour period.

The SFCMM* is a unique mixer that provides more uniform mud at higher rates than that provided by other mixers available.
Use of the Engineering Simulator for Drilling for Evaluating and Designing Drilling Rigs
Authors: Brett J. F. , Yoder D. L.
Published: December 2007

Drilling personnel typically base the selection of a Drilling Contractor and rig on their subjective evaluation of how well various rig components will meet their envisioned drilling needs. This evaluation process involves rating the capabilities of the drawworks, mud and solids control system, mud pumps, tubulars, power generation equipment, and ancillary equipment such as blow-out preventers, choke manifolds, automatic driller, and instrumentation. Consideration must also be given to the type of geology that the planner expects to encounter. However, the true performance or capability of the selected rig is not known until it is contracted and used to drill a well. Many times the advertised capability of the rig is not achieved in the field.

An Engineering Simulator for Drilling (ESD) has been developed that can simulate the operation of any SCR type drilling rig in any type of drilling environment. The simulator has been used to compare different equipment for specific drilling programs and has predicted which rig would be the best rig to drill the well. The simulator has also been used to up-grade the design of existing rigs to optimize their performance.

This paper presents an overview of the drilling rig simulation algorithms and how they are used to emulate an actual drilling rig. The paper also gives examples of how the simulator is used to evaluate rig capabilities, and how this ability to evaluate rigs, with an unbiased systems approach, can be used by operators to select rigs on a performance basis.
Design of Atmospheric, Open-Bottom Mud/Gas Separators
Authors: Butchko D. , Davies G. E. , Fuchs G. T. , Reid R. R.
Published: December 2007

This paper will aid in sizing, material selection, installation, and operation of atmospheric open bottom mud gas separators (AOBMGS) for onshore well control operations. It is based on a document prepared for the Canadian Petroleum Association (CPA) entitled " Guidelines and Specifications for Designing Mud Gas Separators For Use In the Canadian Drilling Industry".1 Some modifications to the CPA document have been included in this paper.
Zistersdorf: The Deepest Well in Europe With a TD of 8553 m (28,061 ft)
Authors: Moritz J. , Spoerker H. F.
Published: December 2007

OEMV drilled a replacement well in the Vienna Basin which reached a TD of 28.061 ft, after loosing the first well by a kick. Extensive planning was necessary to handle hostile conditions such as high pressure, high temperature, failure of casing couplings caused by H-induced embrittlement despite the absence of H2S and cementing problems. The design, techniques followed and experiences are presented.
Applications of Measurements While Drilling (MWD): Development of the East Breaks Field, Offshore Texas
Authors: LeGros F. W. , Martin C. A.
Published: December 2007

In October of 1982, after drilling the seventh well on the Cerveza platform in offshore Texas waters, nearly four days were spent attempting to record wireline logs. Getting wireline logs to total depth was typical of problems on previous wells in this area. Measurements While Drilling (MWD) utilizing resistivity and gamma ray, was evaluated on the eighth well and has been used successfully on the subsequent eight wells to date. This initial use of MWD for geological evaluation led to further applications reagarding drilling optimization and directional control.
Practical Rig-to-Office Data Communications
Authors: McCoy R. S.
Published: December 2007

In recent years, Data Communications has become one of the fastest growing technologies. Linking computers with telemetry, and founded upon the clear and obvious perception that accurate and timely information is of great value to the appropriate users, Data Communications has been eagerly accepted by industries that depend upon clear visibility and control of operations, insightful interpretation of available data, and critical decisions based upon economic objectives.

Historically, oil companies have been conservative in adopting systems and techniques that alter or impact traditional oilfield processes that affect the collection, review and reporting of oilwell drilling data. This reluctance has been based upon a lack of understanding of new technology, a natural concern for the problems of implementing that technology with a minimum of disruption, and a legitimate concern for justifiable cost.

This paper provides a brief overview of the potential impact of Data Communications technology on the oil industry. Based upon experience in the oilfield, it addresses the practical aspects of implementing this technology both at the rig and in the office. The process of involving and gaining the cooperation of wellsite personnel is discussed in terms of real-time and "batch" transmission of drilling data, and the extent to which computer expertise is required. Special considerations of wellsite security and office-to-rig Data Communications are also addressed.

Perhaps the most critical aspect of Data Communications concerns economic and operational justification. This paper suggests justification for Data Communications in terms of reduced drilling costs and improved well control.
The Participation And Value Of The Petroleum Engineer In The Oil And Gas Industry
Authors: Hinton C.H.
Published: December 2007

Publication Rights Reserved

This paper is to be presented at the SPE Regional Meeting in Liberal, Kansas, November 18–19, 1965, and is considered the property of the Society of Petroleum Engineers. Permission to publish is hereby restricted to an abstract of not more than 300 words, with no illustration, unless the paper is specifically released to the press by the Editor of the Journal of Petroleum Technology or the Executive Secretary. Such abstract should contain conspicuous acknowledgment of where and by whom the paper is presented. Publication elsewhere after publication in Journal of Petroleum Technology or Society of Petroleum Engineers Journal is granted on request, providing proper credit is given that publication and the original presentation of the paper.

The purpose of this paper is to try to present an industry picture which is based upon trends and statistics that may enable you to see what the overall future outlook may be for the petroleum engineer. No attempt is being made to quantify you as individuals. The obligation which you as an individual have, and the experience and success which you may achieved is pretty much up to you. The prime objective of engineering training is to gain knowledge and, through the application of such knowledge, to make possible the production of the required supply of minerals and raw materials and to utilize such materials to provide a better product to the ultimate consumer at a lower cost. The participation of the petroleum engineer in industry is governed by knowledge, desire, and effort, or, perhaps, they should be re-arranged with effort heading the list. The value of the petroleum engineer is dependent upon what he achieves for himself and for his employer. Petroleum engineering is a relatively new field. In 1900 there were only 3000 engineers classed as metallurgical and mining.
Investigations on Localized Corrosion of Low Alloy Steels in Sweet Gas Production
Authors: Schmitt G. , Steinmetz D. , Engels D. , Bruckhoff W.
Published: December 2007

The resistance of various low alloy steels to mass loss and localized attack under conditions of sweet gas production was investigated in artificial production water at 70–130°C under 4–6 bar CO2 at flow velocities of 3.5–6.2 m/s. Experimental conditions were found for reproducible production of pitting and erosion corrosion and its effective inhibition by dissolved lead salts.
Thermally Stable Polymeric Gellant for Oil-Base Drilling Fluids
Authors: Patel A. D. , Salandanan C. S.
Published: December 2007

A polymeric oil gellant, which imparts thixotropic properties to oil-base drilling fluids has been developed. Present day state-of-the-art additives, such as organophilic clays, various soaps, asphaltic materials and mineral fibers which are used to impart gel structure to oil-base muds have certain limitations. One of the major shortcomings is thermal instability. In addition, some of these additives contribute to undesirable solids buildup. To minimize these problems, we have developed a novel oil-dispersible copolymer from styrene-butadiene and functional monomers. This novel oil-base drilling fluid additive provides a drilling fluid which exhibits a variety of highly desirable properties, such as elevated yield point and a more effective gel structure. This novel additive does not significantly increase the plastic viscosity of the drilling fluid.
Modeling of Permeability Reducing Vertical Conformance Treatments
Authors: Tsau J. S. , Hill A. D. , Sepehrnoori K.
Published: December 2007

Chemical treatments (usually polymer gels) are commonly applied to improve the vertical conformance of oil reservoirs by selectively reducing the permeability in some zones near the well. The results of such treatments have been sporadic and unpredictable; The objective of this work was to define those reservoir characteristics which lead to successful treatments and to provide guidelines for the application of conformance treatments by modeling them with a reservoir simulator.

Several cases have been run to identify the reservoir properties that strongly influence the outcome of a conformance treatment. Among the conclusions that have been drawn from this study are: 1. A low level of reservoir crossflow is conducive to a successful vertical conformance treatment; 2. The contrast in the permeability-thickness product of the reservoir layers is a useful parameter in identifying treatment candidates; 3. Vertical conformance treatments reduce the amount of injected water needed to recover a given volume of oil; and 4. Little sensitivity to the level of permeability reduction is observed as long as the treated region was reduced to a permeability as low as that in the low permeability layer.
Electrolyte-Tolerant Polymers for High-Temperature Drilling Fluids
Authors: Clements W. R. , Nevins M. J. , Scearce F. A.
Published: December 2007

New high temperature synthetic organic polymers are discussed in the light of existing technology and their application in water-base drilling fluids. Salt-tolerant polymeric deflocculants and filtration control agents with high temperature stability are prime considerations for extending the utility range.

Laboratory results from temperature and electrolyte studies as well as rheological measurements to 550°F and 10,000 psi with a new high pressure/high temperature test system are shown. The new polymers can be used alone or in combination with conventional materials. Examples of field use and benefits are described.
Reducing Power Consumption in Rod Pumped Wells: A Digital Approach
Authors: Denesha D. P.
Published: December 2007

Power consumption in rod pumped wells is related to the power used in lifting fluid column loads as well as overcoming dynamic effects and power losses that occur in mechanical equipment. A testing system has been designed and a computer program written that locates and quantifies system losses, comparing them to the power required to drive the entire system.
Operating Experience With a Two-Stage H2S Scrubber Using Caustic Soda
Authors: Siemak J. B. , Gelbs M.
Published: December 2007

Hydrogen Sulfide (H2S) and Carbon Dioxide (CO2) are natural occurring gases produced along with crude oil in many oil fields in California. Natural gas when highly contaminated with these gases has very little commercial value and also causes safety, environmental, and corrosion problems in pipelines and equipment. It therefore must be treated before disposal or blending. The Bremer Fee lease multi-stage scrubber facility was built to remove H S from well-produced sour gas streams, so that the resultant sweet low Btu gases could be disposed off by venting.
On the Equivalence of a Hot Water and Gas Drive to a Steamdrive
Authors: Doscher T. M. , Hosseinmardi M. K. , Baghdikian S. Y.
Published: December 2007

The hypothesis that the recovery of oil by a steam drive could be duplicated by a combination hot water and non-condensible gas drive has been confirmed in bench scale, non physically scaled experiments. Despite the inherent limitations of such laboratory experiments, it is believed that the results point to the potential of a new powerful enhanced oil recovery process for both viscous and high gravity crudes.
The Use of Density Control Foam Fracturing for Selective Proppant Placement in the Bartlesville Formation
Authors: Barber P. L. , Themig D. J.
Published: December 2007

A major consideration in fracture stimulation of the Bartlesville formation in Eastern Oklahoma is the lack of competent barriers to prevent downward fracture growth out of the oil-producing interval and into the water-producing interval. This has resulted in sizeable increases in water production with little or no effective stimulation of oil production.

Attempts have been made to design stimulation treatments to minimize the downward fracture growth through the control of job size and pumping rates. This approach has produced some successful fracture treatments as will be discussed in this paper, but evidence indicates that in many cases proppant has been placed in the water-producing interval despite these measures.

This paper will present a different approach to minimizing water production resulting from hydraulic fracturing. It is based on the assumption that downward fracture growth cannot be sufficiently controlled using existing procedures. This approach will present the use of density controlled foam fracturing to selectively place proppants in the upper portion of the fracture adjacent to the oil-producing interval. Included are case histories of density control fracture treatments as well as those of conventional treatments performed in the Bartlesville. Also included are radioactive tracer surveys to support selective proppant placement using a density controlled foam fracturing process.
Well Damage Hazards Associated With Conventional Completion Fluids
Authors: Patton J. T. , Phelan P. F.
Published: December 2007

With new wells often costing in excess of $1,000,000, productivity must be maximized to ensure commercial success. To achieve high productivity, so essential to the profitable development of new reserves, the use of non-damaging fluids for drilling-in, completion and/or well-killing operations is mandatory. Formulation of a non-damaging fluid compatible with hostile reservoir environment is complicated by hot, high-pressure formations that require fluids having densities greater than that of water.

Clear, solids-free fluids, thought to be the solution, are widely used. These fluids often contain more than 20% dissolved salts, consequently, their chemistry is complex and proper use requires much understanding and experience. There is mounting evidence from field applications that clear completion fluids do not provide adequate protection against formation damage due to salts precipitating in the reservoir. Equally troublesome is the tendency of the clear fluids to deposit fine particulates, mill scale and etc., on the face of the formation thus causing hard-to-remove damage, especially in the case of gravel-pack completions.

Another popular class of high-density fluids is formulated using acid-soluble particulates as weighting agents. In the most advanced fluids of this class, the particles are suspended in water or brine by non-damaging polymers. Use of these fluids avoid all of the residual problems associated with clear, high-density fluids. When extreme situations warrant, particulate-weighting can be complemented with dissolved salts to maximize protection against damage. Any temporary productivity loss due to the particulates in these fluids is restricted to the surface of the wellbore and can be removed by simply washing the formation face with hydrochloric acid.
Using a Microcomputer to Perform Design Calculations for a Sucker Rod Pumping System
Authors: Purcupile J. C. , Nicol T. H.
Published: December 2007

Sucker rod computations in accordance with Ref. 1 are both tedious and time consuming. Each time a pumping parameter is changed, such as rod designation, pumping speed, the calculation must be repeated.

Three programs to handle these calculations have been written for the Hewlett Packard HP 87 XM microcomputer.

The first program is a dynamic analysis program for either an API Class I or Class III pump.

The second program performs the detailed calculations in accordance with Ref. 1 and prints a form that is essentially the same as the form No. 11L-1 of Ref. 1.

The third program performs the "RP 11L calculation" for a number of rod designations printing out: Total rod weightPump displacementPeak polish rod loadMinimum polish rod loadPeak torquePolish rod horsepowerMaximum stressRatio of daily production to polish rod horsepower

for each API rod number in the range of API rod numbers being considered.
A Perspective on Tailored Pulse Loading: A New Approach to Oil and Gas Well Stimulation
Authors: Stoller H. M.
Published: December 2007

Tailored pulse loading is a descriptor for intermediate strain rate rock fracturing processes. These processes are capable of generating multiple fractures in the reservoir rock when the proper energy-time profile is applied to the wellbore. Such multiple fracture networks have a high probability of intersecting natural fractures; hence initial applications have focused on low permeability, naturally fractured formations.

Tailored Pulse Fracturing, a tailored pulse loading process, has undergone developmental testing in the San Andres formation in the Permian Basin. These tests have provided insights into the fracture characteristics and the production effects of multiple fracture networks. Concurrently, mathematical models have been developed to predict the performance of Tailored Pulse Fracturing.

Discussed in the context of explosive and hydraulic fracturing, predicted fracture lengths and widths are presented as a function of applied energy and formation properties. Productivity indices are proposed based on multiple fractures affecting changes either in effective reservoir permeability or effective wellbore radius. Enhanced production results indicate either natural fracture intersection or a synergistic blend of production mechanisms.

Field tests in the San Andres are discussed and production data are analyzed. The data is interpreted as indicating long fractures (>100 feet) can be created and that long term conductivity is maintained.
High Capacity Materials Handling Systems For Commercial Extraction Of Oil From Solid Hydrocarbons
Authors: Whikehart Richard E.
Published: December 2007

Introduction:

The materials handling industry has a keen interest in recent developments in possible oil extraction from tar sands, oil shales and coals. The existence of vast reserves of these raw materials have stimulated the imagination of forward thinking people and organizations for many years. Much has been published about specific plans and projects and much more is to come. Known oil shale deposits in the Green River formation in Colorado, Wyoming, and Utah alone have a potential recoverable oil content exceeding one trillion barrels. Tar sands in Alberta, Canada, in McMuray formation alone have indicated reserves of the same order of magnitude. Bituminous coal reserves in the United States are nearly one trillion tons. World reserves of these materials are doubtless many times greater. A vast new segment of a vital industry may be in the making. To the materials handling industry, a trillion barrels of potentially recoverable product is translated into a potentially large number of unique, high capacity handling systems. For instance, at 50,000 barrels per day per plant, it would take some five hundred plants to recover just one of the trillions of barrels in one hundred years.
Operational Experience With a Long-range, Multi-channel Acoustic Telemetry System.
Authors: High G , Carman R J
Published: December 2007

This paper describes the design, installation, and long-term operation of a modular subsea acoustic data acquisition system in the Duncan/Argyll field. North Sea. This equipment is presently providing on-demand pressure data from eight satellite locations at ranges in excess of seven kilometres. The discussion covers the use of in-field noise measurements for optimizing system performance in a high noise environment.

Two main sections cover firstly platform installation and seabed installation of the subsea transceiver. Secondly at the remote wellhead locations, the acoustic transponders are described. Cost factors, as compared with hardwired or diver-monitored data acquisition systems are discussed.

Modular design permits convenient addition of other data channels and/or extra remote subsea units. The surface equipment installed at the platform is software controlled so that display and data logging can be configured according to operator needs. Vairiations of the same basic system are discussed, as currently in use for subsea pipeline valve actuation, and submersible flowline tow-out instrumentation.

Results of several years of operational experience in various offshore applications give confidence that, when properly considered in system design, an acoustic telemetry system can function reliably at useful ranges in the offshore environment.
Statistically Valid Log Analysis Method Improves Reservoir Description
Authors: Moss B , Harrison R
Published: December 2007

Oil companies spend vast sums on the collection of log data. Because of the analysis methods generally available, not all of these data are used, with much being discarded. All data, even from "bad holes", potentially can provide useful information. Every company currently has a great deal of data either being analysed, or about to be analysed. Much of these data will never be used, which is both extremely wasteful and potentially dangerous since this inability to extract information can often lead to incorrect conclusions.
The Thistle Field – Analysis of its Past Performance and Optimisation of its Future Development
Authors: Bayat M G , Tehrani D H
Published: December 2007

The Thistle Field geology and its reservoir performance over the past six years have been reviewed. The latest reservoir simulation study of the field, covering the performance history-matching, and the conclusions of various prediction cases are reported.

The special features of PORES, Britoil in-house 3D 3-phase fully implicit numerical simulator and its modelling aids as applied to the Thistle Field are presented.
AC Drives for Drilling
Authors: Olsen S O , Knudsen S
Published: December 2007

Until now direct-current motors fed by thyristor rectifiers have dominated as variable-speed drive systems for oil-drilling applications.

During drilling of a test well at Rogaland Research Center in Stavanger, Norway, a new drilling system "The Power Swivel" was tested and the conventional DC motor/SCR system was replaced by an asynchronous motor fed by a GTO frequency converter.

Whilst an enclosure of protection class Ex(P) is required for DC motors operating in hazardous area, asynchronous motors can also be built to protection class Ex(d), (e), or (n) for this type of application.
The Use of Casing Patches to Improve Workover Success Rates
Authors: Neely J D
Published: December 2007

Until 1983, traditional cement squeeze techniques were used to shut off excess water production from wells in the Forties Field. The success rate was low, some 50% of workovers failing within 5 days of the well being returned to production.

Casing patches over 120 feet long are now being run to cover the squeezed off perforations and workover effectiveness has increased dramatically. Radioactive tracers are employed to ensure accurate depth control as the patches are run and set on drillpipe.

It is envisaged that continuous patches could be run when extremely long perforated intervals are encountered and alternative uses, e.g., to repair mechanically damaged casing, can be foreseen.
Process Systems the Role of Quality Assurance in Safety
Authors: Crawley F K , Brown W A F , Scott D S
Published: December 2007

This paper outlines some techniques whereby the safety of an installation may be improved by attention to "quality" in a similar manner to Quality Assurance.

The techniques mentioned are to be treated as illustrative and indicate the manner in which they change as a project progresses.

The paper indicates areas where it is believed there is potential for new techniques utilising the strength of modern computers.
Ultra-Violet Disinfection of Injection Seawater for Secondary Oil Recovery
Authors: Brunner H , Klein H P
Published: December 2007

Today diminishing oil reserves force us to seek ways of increasing the yield of existing resources.

Some years ago oil was mainly recovered by means of the natural pressure of the oil bearing formation. When natural pressure decreased, the source was regarded as exhausted, although considerably more than half of the total oil quantity remained in the fine pores of the oil bearing rock strata. Meanwhile techniques have been developed to exploit a greater part of these neglected reserves.

The principle of all these techniques is that the pressure in the oil reservoir is maintained in order to force the remaining oil towards the well-bore. One of the methods to achieve this is the injection of water under high pressure into the oil-bearing stratum. Depending on the location of the recovery point fresh water or sea-water is used.
North Sea Produced Water Systems
Authors: Bond C R
Published: December 2007

North Sea platform produced water systems were designed up to 10 years ago utilising plant largely developed for other industries. Generally the systems were designed without adequate knowledge of the produced water itself or the flow-rates. Many fields are now experiencing injection water break-through and consequently far greater flow rates than envisaged. By reference to Britoil's Thistle and Beatrice platforms, this paper describes some of the short-comings of systems, the resultant modifications and extensions, and performance data before and after modifications.

By applying basic process principles proven by both scale model work of fluid flow patterns and also offshore trials, the existing equipment was drastically modified. Together with many ‘minor’ changes, system performance has been raised by 25% to the required levels. The minor changes were often of a relatively detailed nature and emerged from experience of corrosion, scale deposits, process transients, and start-up and shut-down phenomena.

The paper addresses the fundamentals of produced water treatment technology and presents operating data from:- Laboratory model testing and offshore pilot trials of cartridge coalescers.Modified tilted plate assemblies.Induced and dissolved gas processes.System interactions and practical operating problems.

This work will be relevant to some extent to all produced water systems as:- –Improvements in the reliability and understanding of the clean-up processes are necessary to obtain the plant performance to satisfy reservoir requirements.–Testing totally new plant and modified equipment is essential to enable improved equipment designs to be brought forward.
The Dissolution of Scales in Oilfield Systems
Authors: Clemmit A F , Ballance D C , Hunton A G
Published: December 2007

The phenomenon of scale formation has been experienced by generations of different races whenever water has been used. It was formed in Roman aqueducts and canals and is also found in the present day in the most modern oil production operations. The most commonly found scales in this industry are the carbonate and sulphate salts of calcium, barium and strontium which can be encountered from the reservoir rock itself all the way through the complete process train to the oil exporting system. It can therefore be appreciated that considerable decreases in efficiency of equipment and reservoir production can result from this.

The need to maintain high rates of oil production makes this a serious problem and remedial action is desirable. This can be in the form of problem and remedial action is desirable. This can be in the form of inhibition to prevent scale formation, or, where scale is already present, removal is required.

This paper outlines the mechanisms of scaling and the principles of scale dissolution using sequestrants. Details of treatment techniques, especially in downhole situations, are also presented.
Ultrasonic Corrosion Condition Monitoring – A Systematised Approach
Authors: Yates A.
Published: December 2007

The technique of taking ultrasonic thickness readings as a basis for assessing corrosion and erosion damage on structures and pipework systems is an established means of obtaining condition data.

To ensure that surveys carried out in this way are relevant and useful, several conditions must be met: Individual readings must be accurate and the measuring system must be capable of ignoring paints and coatings at the test point.Test points must be appropriately positioned.Sufficient points must be taken to give a representative sample.Reporting must be in a format which is readable, flexible and capable of highlighting anomalies.

Following extensive experience in onshore and offshore corrosion condition surveys, systems have been evolved which have improved the efficiency of this approach in all the above areas.
An Electrical Machine Monitoring System for the Offshore Industry
Authors: Penman J. , Dey M. , Smith J. R. , Bryan W. E.
Published: December 2007

Condition monitoring and its associated instrumentation may be considered to involve designers, machinery manufacturers, commissioning engineers and most importantly offshore operational staff. It is in this ultimate stage where condition monitoring systems aid the operator by continually assessing the health of the equipment and plant during its planned life. However, when considering the usefulness of such a system, it is in the early phases of system design that a great deal of attention must be given to the type of plant to be installed, and the expected variation of parameters during healthy operation together with the tolerance on these parameters that must be allowed prior to a probable fault condition being reported or acted upon. The electrical machine monitoring system described in the paper intrinsically takes account of this latter consideration and is developed on the basis of sensing the leakage magnetic field of the machine. An analysis of this field directly leads to the discrimination of a variety of fault types. A description of the system is given and results are presented in which a low cost microprocessor based system is used to identify faults in both synchronous and induction machines.
Review of and Experience with Emergency Shutdown Systems
Authors: Huse J. R.
Published: December 2007

The Emergency Shutdown (ESD) System is defined as a system which immediately terminates all production activity and other systems not essential for platform emergency operation. The ESD-systems should be independent from and in addition to other systems and generally based on a "fail-safe" principle.

Experience with ESD-systems is fairly good. However, further improvements could be done on sensors and valves and on man-machine interactions.

Reliability of computer systems to be closely monitored; e.g. for internal faults.
High Reliability Riser Tensioners for the Hutton TLP
Authors: Myers R. J. , Adam L. J. , Harvey D. W.
Published: December 2007

This paper details the approach taken to maximise the reliability of the Hutton Tension Leg Platform (TLP) production riser tensioners. The design, development, testing and operational performance of the tensioners are described. In addition the paper outlines the reliability analyses and quality assurance procedures which are used. Operational experience of the production riser tensioners installed to date on the Hutton TLP is summarised. Conclusions are drawn and recommendations made for future work of this type.
Deep Water Jacket for North Sea Conditions
Authors: Henriksson A K
Published: December 2007

The Hydeep platform has in our analyses demonstrated good fatigue behaviour, especially in its lower part. Its fabrication schedule is also comparably shorter due to being split into two units. The platform can also be extended for use in greater water depths than the 305 m it is presently analysed for.
Design Considerations for a Deepwater Pile-Founded Buoyant Platform
Authors: Basu A. K. , Raznahan M.
Published: December 2007

The paper presents a new compliant platform concept for deepwater drilling and production. Like an articulated column it derives its stiffness from the large buoyancy provided near the sea surface, but it does not use any mechanical articulation. Instead, the rotational compliancy is achieved here by an ingenious design of the pile foundation system, similar to the one adopted in the Lena Guyed Tower. The principles underlying the design of the various components of this structure are discussed, using as an illustration a structure with a total deck load of 30,000 Tonnes for a 350m water depth northern North Sea field.
A Case Study of a Typical Automatic Tank Battery
Authors: Peebles Charles T.
Published: December 2007

Introduction

The purpose of this paper is to present a discussion of a typical automatic tank battery. In this case, the installation is Mene Grande's Guara Discharge Station N7. This battery was converted to automatic operation late in 1957 and has since been operated on a test basis to determine the practical value of such equipment for service in Meneg's Eastern operations.

The battery is equipped with an electro-pneumatic well-test system and a positive displacement meter type automatic custody transfer system. A detailed explanation of these systems is included in the paper.

When it became apparent that automatic operation of discharge stations might possibly result in savings due to reduced capital expenditure and lower operating costs, it was decided that one typical discharge station be automated. Both the equipment and the procedures involved were to be evaluated to determine their practicability for service in future Meneg operations. Guara Discharge Station N7 was selected as the test station. The selection of this particular battery as the test site was influenced by its proximity to San Tome, availability of electric power and to the fact that a variety of crude types are produced to the station by natural flow, gas lift, and by pumping. Table N1 illustrates the characteristics of the various individual wells produced to the station.

The conversion to automatic operation was completed in November 1957. An electro-pneumatic well test system and an automatically controlled positive displacement metering system comprise the automatic features of the station.