bluuebunny/crossref_metadata_2025_split huggingface dataset:
Fire-Resistant Wellhead Equipment for Offshore Platforms
Authors: Williams Michael R. 
Published: December 2007

ABSTRACT
A new generation of fire-resistant wellhead equipment has been developed for offshore platforms. This paper presents the design concepts and principles of operation of this new equipment, and it describes the engineering approach taken during its development.
These new wellheads and Christmas trees have survived numerous laboratory fire tests which simulated offshore platform fire conditions. No leakage was permissible during the test burns nor during the subsequent cooldown periods. The laboratory fire test results confirmed the performance predicted by computer Finite Element Analysis and verified the design procedures employed.
This new fire resistant wellhead equipment promises to significantly reduce the fire hazard associated with the production of oil and gas from offshore platform wells.
Arun Field Tubular Performance, Quality Control and Operating Experience
Authors: Ridwan Amir , Hull K. B. 
Published: December 2007

ABSTRACT
This paper discusses the experience of and the solution to problems which have arisen concerning tubular products used by Mobil Oil Indonesia, Inc in Arun Field gas well completions.
Mobil Oil Indonesia has developed and implemented an intensive Tubular Quality Control Program to maximize the quality and integrity of the tubular products which are subjected to the extreme conditions of this prolific gas field.
The Tubular Quality Control Program which monitors the specified tubular quality from the steel mill to the rig floor has successfully maintained safe and dependable well operations with higher tubing integrity.
Gas Disposal Aboard A Floating Production Facility
Authors: Otten Lawrence E. , Scoles Lee R. 
Published: December 2007

Abstract
The Cadlao Floating Production, Storage and Offloading (FPSO) Facility has on board equipment to separate the oil, water and gas produced from two subsea wells. The produced natural gas is used to fire the original ship's steam boilers and excess gas is disposed of through an enclosed vertical flare.
The Cadlao produced gas contains up to 6000 ppm H2S and added safeguards were necessary for burning the sour gas in the boilers and in the flare stack.
Gas compression equipment installed to allow gas injection into the well-streams to reduce the hydrostatic head of the produced fluid column has not yet been used.

BOILER FUEL
The converted tanker was equipped with two 50000 kg/hour standard marine boilers. The boiler room equipment was completely redundant to insure steam for vessel maneuverability at all times. The converted vessel does not require steam for maneuverability and with a 750 kw diesel standby generator, and a 330 kw emergency diesel generator in addition to the two original 700 kw steam-driven generators can be without steam power to extended periods of time.
The FPSO boilers operate in two modes:producing operations where the distillation plant and one 750 kw steam-turbine generator are in use oroffloading when the steam-driven cargo and stripping pumps ore also added to the boiler load.
Either boiler has adequate capacity for both load conditions, and only one boiler is fired at a time. The boiler not in use is alternated each month to assure continued proper operation of both boiler systems.
All fuel gas lines are made up of concentric piping up to the individual boiler face. At the boiler face, the fuel gas controls and piping are enclosed in an exhaust hood which will exhaust any sour fuel gas leaked from the boiler face piping/controls (see Figure 2). The pressure reduction from the exhaust fans at this location is sufficient to overcome the tendency of H2S gases to sink to the lower levels of the engine room. The exhaust fan failure and HAS and explosive level located in the exhaust hood are interlocked with the boiler fail-safe shut-dawn system. Other H2S sensors are strategically placed about the engine room.
p. 11–61 p. 11–61
Development Drilling Problems Offshore Malaysia
Authors: Osman Mohamed Nor , Maung Mya 
Published: December 2007

SUMMARY
This paper highlights the major drilling problems encountered in the field development programmes offshore Malaysia from 1978 to mid-1983. The major problems identified were pipe sticking which was common in all the areas and top hole drilling problems encountered in a few fields offshore Sabah and Sarawak. Generally, the problems were related to drilling deviated wells through the soft and unconsolidated formations common in this region. Preventive measures employed by the Contractors have been effective in overcoming these problems in the later years of the period under consideration.
Cost Effective and Maintenance Effective Design for Geothermal Power Plants
Authors: Bouma John 
Published: December 2007

ABSTRACT
This paper encompasses a number of considerations that can be made for the design and construction of a geothermal power plant. The considerations consist of both practical approaches and economic trade-offs of design concepts. Throughout the design, simplicity is the key note in the shaping of this geothermal power plant.
During the course of the design, the elements that initially appear problematic are turned around by means of innovative design concepts, resulting in an effective and economical overall design.
This paper also discusses the impact of climate and elevation on the construction of the plant. The relation of starting construction and the season in which construction is started, is critical.
The use of easy maintainable auxiliary equipment is considered by tailoring the auxiliaries to the available overhauling facilities of the country for which the plant is designed.
Aerated Fluid Drilling Observations in Geothermal Operation in Luzon, Philippines
Authors: Rizo T M , Cuenca A P 
Published: December 2007

ABSTRACT
This paper compliments the potential use of aerated fluid drilling in oil-gas operation of which the techniques in application was further extended to geothermal energy drilling.
Compared with the use of conventional mud in both oil-gas and geothermal drilling operation, the benefits of aerated fluid cannot be denied. However, the developed utilization of blind drilling in geothermal operation in Luzon, Philippines were observed to be more beneficial.
This paper highlights the incremental costs involved in using aerated fluid compared with blind drilling with water in geothermal operation within the 8½" hole interval when total lost circulation zones are encountered.
Review of the Mechanical Design Requirements for Offshore Pedestal Cranes
Authors: Alexander P E , Wong W 
Published: December 2007

ABSTRACT
Modern design philosophies for offshore cranes require the structural components to be designed for the dynamic loadings experienced in the offshore environment. If these predicted impact loads are applied to the relevant winch load-paths, then the ccmponents in those load-paths can be appropriately designed. Specifications do not at present, require the operator to predict at the enquiry stage, the service duty and load spectrums for the crane. When these are specified by the operator, the designer is able to apply appropriate stress levels to the components to attain the required crane life.
H2S Safety Aboard an Offshore Production Facility Handling Crude Oil and Associated Sour Natural Gas
Authors: Devries Peter , Scoles Lee R 
Published: December 2007

ABSTRACT
This paper describes the safety system and training for personnel on board the floating production storage and offloading (FPSO II) currently working in the Cadlao Field, offshore Palawan in the Philippine Islands. (See Figure 1). The crude oil being produced has weiistreσm hydrogen sulfide concentrations up to 6000 PPM. Concentrations of hydrogen sulfide at 700 PPM or higher can be immediately dangerous to life and every effort must be made to ensure personnel safety.
Piper Field: Operational Aspects of Drilling/Completions/Workovers/Data Acquisition And Well Performance
Authors: King Paul A. 
Published: December 2007

Abstract
This paper presents a brief insight into the operational aspects of the development of Occidental's Piper field. The paper discusses all operational aspects of the development programme commencing with the drilling and initial completion phase, then moving into a discussion of the various types of workover which have taken place to date and concluding with a section reviewing the data gathering programme that has been running throughout the life of the field. This final section also shows the degree of accuracy that has been attained in matching predicted to actual well performance.
Planning and Drilling a 24,325-Ft Well in Southwest Oklahoma's Anadarko Basin
Authors: Welch E. R. 
Published: December 2007

ABSTRACT
Texaco drilled a well in southwest central Oklahoma which reached a total depth of 24,325 feet. This test presented a unique challenge both in planning and implementing the drilling program. The design, techniques, and practices followed to attain an optimum drilling program are presented.
A Decade of U.S. Drilling … Trends, Characteristics, Outlook
Authors: Dougherty Tom 
Published: December 2007

Abstract
Despite the downturn in drilling attendant upon price uncertainties which surfaced in late 1981, completions recorded in the U.S. in 1983 stood second only to the 1982 total.
Deep drilling declined more sharply in relation to 1982. And, pure exploration… new field wildcats drilled… declined. The new field wildcat success rate was less than 17 percent, down from a four year average of more than 18.5 percent.
Oil wells, as a percentage of total completions, increased. Gas wells, however, fell back to 18 percent, the lowest level in a decade.
Crude and condensate production remained about level with prior years since drilling reversed the early Seventies downward trend in production. Gas production declined, not because of ability to produce, but because of decline in market.
In the first four years of the Eighties, some 306,000 wells were completed. This is approximately 10 percent of all domestic drilling to date.
Exploration below 15,000 feet over the four years has had a success ratio of 14 percent demonstrating the additional potential remaining to be exploited under proper economic conditions.
Demand will increase through most of the remainder of the century, assuring upward progression of prices and, consequently, continued high levels of drilling. This is essential to the welfare of the nation, since in recent years reserve replacements have not equalled withdrawals.
In 1984 an average of about 2,600 rotary rigs will be active and it is expected that approximately 70,000 wells will be drilled in the United States.
CO2 Corrosion in the Anadarko Basin
Authors: Browning D. R. 
Published: December 2007

Abstract
Some high pressure, temperature and volume gas wells located in the Anadarko Basin area of Washita, Beckham, and Roger Mills counties of Oklahoma have demonstrated in several cases severe corrosion rates which has led to surface equipment and tubular failures. This paper deals primarily with the El Paso Exploration Company's approach to the corrosion problem in producing gas wells.
A basic theory on the mechanism of CO2 corrosion and the identification of this type of corrosion will be presented to insure a general understanding of this type of corrosion. A discussion on the detection and monitoring system used with comparison of water and gas analysis, visual inspections, ultrasonic thickness measurements and coupon installation. The procedures which determines whether or not a well may require corrosion treating, along with the method by which the wells are treated, and the amount of protection which can be expected from individual treatments. Some specific problems and personal observations will be presented on the corrosion that has been found in the field which may be utilized as a guide or a better indication that a corrosive environment exists. A discussion on corrosion and a corrosion program as it affects economic, environmental and personal safety aspects should a failure occur is also presented.
Drilling: A Long Way To Go
Authors: Holley G. T. 
Published: December 2007

ABSTRACT
These are difficult times in the oil and gas industry. With the changes currently taking place in daily operations, drilling contractors and service companies have to remain flexible enough to adapt and survive.
The period from 1980-1982 saw the industry become cost inefficient. No one segment of the industry could be blamed for the inefficiency. All were strapped with more work than they could do and were burdened by a shortage of qualified people.
Now with the shakeout slowing, the industry can regroup and reevaluate what has been learned during the recent period of unprecedented growth and activity.
With the tight money situation, operators will be most concerned about drilling good prospects and keeping costs reasonable. The drilling contractor's and service companies' prime goal will be to survive. Their emphasis will be put on increasing rates and hoping for a quick return to profitability or at least a positive cash flow.
Application of Foamed Portland Cement to Deep Well Conditions in West Texas
Authors: Bozich M. P. , Montman R. C. , Harms W. M. 
Published: December 2007

ABSTRACT
Inherent in all casing programs there exists one area of special concern, and in deep well drilling that usually involves the setting of a long intermediate string of casing. The presence of weak, pressure intolerant lost circulation zones often makes cementing of the intermediate string the most difficult and expensive cementing operation encountered during completion of the well.
The use of an economically attractive and field proven cementing technique has resulted in more predictable results than previously established methods. The application of foam cement at slurry densities equivalent to or less than the drilling fluid weight has resulted in placement of quality cement higher above frail zones than previously possible in a single-stage cementing operation.
Case histories, economic analysis, physical properties and developmental background of foam cementing as applied to deep well drilling will be presented.
The Leaking Liner Top
Authors: Agnew J. W. , Klein R. S. 
Published: December 2007

ABSTRACT
An imperfect cement seal at the top of a liner will allow gas from below to leak into the drilling annulus above a production liner. Conversely, with a pressure differential toward the formation, fluid can be lost from the annuli during drilling or during stimulation for production. Since perfect liner cementation is an elusive target, this paper will discuss briefly the cause and effect of the leaking liner top and list the options available for solving the associated problems.
This paper was written to address the problems encountered in the drilling and completion of deep high pressure gas wells; however, much of the information can be applied to wells drilled and completed under less rigorous conditions.
Shale Production from the Britt Formation in Northwest Caddo County
Authors: Dutton K. , White J. , Johnson R. , Bemis R. 
Published: December 2007

ABSTRACT
A major, and costly, problem in producing gas in the Anadarko Basin can be the production of shale. Shale production can plug surface equipment, the wellbore or cause collapse of a properly designed casing or liner. An examination of five wells that have "shaled off" in northwest Caddo County is discussed to draw some conclusion as to why shale was being produced. Each of these five wells had a production potential of at least 2 MMCFD in the Springer-Britt Sand. Production was lost and the zone had to be abandoned.
This paper examines the Britt Formation, where shale problems have been encountered. Potential solutions to cementing practices, perforation placement, stimulation techniques and production practices are outlined. Results from the five-well study are correlated and recommendations for future completions are made. These correlations and recommendations should be applicable to other geopressured reservoirs with shale production problems.
In Search of the Apache Key
Authors: Grace R. D. , Storts P. D. 
Published: December 2007

Abstract
In June, 1981, Apache Corporation of Minneapolis completed the Key No. 1-11 in the Upper Morrow at 16,000 feet in Eastern Wheeler County of the Texas Panhandle. The Key No. 1-11 was one of the best Morrow wells ever drilled in the Anadarko Basin having 90 feet of porosity in excess of 20 percent with an original COFP of 90 MMSCFPD. On Sunday afternoon, October 4, 1981, after being shut-in for 78 days waiting on pipeline connection, the Key No. 1-11 inexplicable erupted, blowing the wellhead, 80 feet of 2-7/8" tubing, 80 feet of 7-5/8" casing, and 12 feet of 10-3/4" casing from the well. The Key was destined to be referred to as the biggest blowout in Texas history and to become a first in many areas before it was finally killed on February 8, 1983, when the Key No. 3 relief well intercepted the 5" liner in the Key No. 1-11 blowout at 15,941 feet TVD. The expeditious intercept was made possible by extensive study and preplanning, the assistance of interested individuals within the industry, the dedication and determination of Apache management, and diligent study of all techniques used for determining the location of one well bore from another including Passive Magnetic Analysis, Ultra Long Spaced Electro Log Analysis and Active Magnetic Analysis (ELREC). This is the story of the incredible intercept, the deepest ever made in the history of the industry.
Nonacid Reactive Solution for Deep Well Stimulation
Authors: Pendergrass J. , Campbell P. , Bell D. , Bishop M. , Copeland J. 
Published: December 2007

ABSTRACT
Certain formations in the Anardarko Basin have not responded well to acid-base cleanup or breakdown treatments. The use of a Nonacid Reactive Solution (NARS) for deep wells where both formation sensitivity and excessive corrosion of tubular goods present problems can produce improved well response. Laboratory analyses of the Morrow, Red Fork and Springer formations in the Anadarko Basin justify the use of NARS for stimulation treatments in these formations.
Laboratory data and production results demonstrate that NARS can be used as an economical and effective method of mud removal in wells which are drilled with oil-base mud. Further studies investigate the effect of NARS on downhole tubular goods. Well histories in the three formations support the effectiveness of the fluid, and the variety of treatment designs dictated by the diverse formation characteristics demonstrates the versatility of NARS.
By concentrating the study of rock lithologies, core and laboratory analyses, and production results, NARS can be used in breakdown and cleanup treatments more effectively than acid-base fluids in sensitive formations.
An Analytical Model for Water/Gas Miscible Displacements
Authors: Jenkins M. K. 
Published: December 2007

Abstract
This paper describes the solution to a steady-state analytical model for gravitational segregation in a water-alternating-gas (WAG) miscible displacement. The model, introduced by Stone (1), provides a conceptual framework for understanding the segregation process. The analysis is extended in this paper to obtain a closed-form solution to the equations, which allows one to easily estimate the incremental recovery above waterflooding for homogeneous reservoirs. This solution is useful in the design of high-recovery WAG floods. Results from the model indicate that recovery increases with dimensionless viscous-gravity ratio (VGR), which is a measure of the volume in the reservoir required to obtain complete segregation of water and gas injected into a well. The model may be used to show how changes in fluid and operating conditions affect recovery. Recovery may be increased either by increasing injection rate or solvent viscosity, or by reducing pattern area or water-solvent density difference.
The reservoir model consists of three distinct zones: a top zone in which only gas is mobile, a bottom zone in which only water is mobile, and an intermediate mixture zone in which the mobility is determined by the water-gas ratio of the injection mixture. Simple expressions are derived that define the boundaries of these zones at any location in the reservoir. These expressions are integrated to obtain ultimate recovery as a function of zone mobilities, injection water-gas ratio and viscous-gravity ratio (VGR). Recovery is shown to be a linear function of VGR for VGR less than one; for VGR greater than one, a logarithmic dependence is obtained. The same recovery expression governs both rectangular and radial geometries.
The governing equations and assumptions are discussed in this paper. The equations are solved, and example calculations are presented. Comparisons are made with numerical simulation results, and the agreement is good. The equations are examined parametrically, showing the effect on recovery of changes in water-gas ratio and zone saturations. A simplified method for using the model to estimate recoveries for VGR less than one is discussed. The method used to determine zone saturations is also described. Sufficient detail is provided to permit recovery calculations for any set of reservoir data.
Effect of Varying Polyacrylamide Molecular Weight on Tertiary Oil Recovery From Porous Media of Varying Permeability
Authors: Ball J. T. , Pitts M. J. 
Published: December 2007

Abstract
Three different molecular weight emulsion polyacrylamides (PAA) have been tested for their ability to recover oil from a multi-permeability Berea core system. Injection of a 6.5 × 106, 17 × 106, and 36 × 106 molecular weight PAA resulted in oil recovery from the multiple permeability core systems of 53.4, 63.7, and 57.2 percent of the waterflood residual oil, respectively. In tests with 15 g/kg Na2CO3, injection of the polymer systems resulted in recoveries of 65.6, 75.3, and 68.0 percent of the waterflood residual oil, respectively. In the presence of alkali, the injection of high molecular weight PAA resulted in the reduction of fluid flow into the medium and low permeability cores with 70 to 75 percent of the tertiary oil being recovered from the high permeability core. Decreasing the PAA molecular weight to 17 × 106 and subsequently to 6.5 × 106 resulted in an increasing amount of fluid flowing through the low and medium permeability cores. While decreasing the molecular weight of the PAA resulted in increased fluid diversion, the 6.5 × 106 molecular weight PAA recovery efficiency was less than either of the other two polymers in the high permeability core.
The data indicates selection of too large a polymer can result in less than maximum oil recovery from a heterogeneous permeability reservoir as a result of lower sweep efficiency. Selection of too small a polymer can result in less than maximum oil recovery from a heterogeneous permeability reservoir as a result of decreased oil recovery from the high permeability zones. Proper selection of polyacrylamide for a heterogeneous permeability reservoir either in the presence or in the absence of alkali will maximize oil recovery.
Quantification of Viscoelastic Effects of Polyacrylamide Solutions
Authors: Heemskerk J. , Janssen-van Rosmalen R. , Holtslag R. J. , Teeuw D. 
Published: December 2007

Abstract
Beyond a critical rate of flow in cores the viscoelasticity of polyacrylamide solutions is reflected by shear thickening behaviour. Practical information is provided on the critical flow rate and magnitude of shear thickening and their dependency on core permeability, temperature, molecular weight and concentration of commercial polymers. To describe the onset of shear thickening, critical Deborah numbers were calculated using fluid relaxation times obtained by oscillation rheometry. Using three core-flow parameters, viz. the critical flow rate and two power-law exponents, the viscoelastic effects are quantified.