bluuebunny/crossref_metadata_2025_split huggingface dataset:
Improvement in Drilling Performances Through Nine Khuff Wells
Authors: Al-Busaidi H. , Du Charlat A. Peyredieu , Rouatbi R. 
Published: December 2007

SUMMARY
ADMA-OPCO drilled its first deep Khuff well using various types of tooth and diamond bits at very high cost/ft. Through various trial runs, turbodrilling with diamond and polycristalline bits proved to be most efficient method to drill the 12 1/4" & 8 3/8" phases.
By using the right bit programme and reducing the sticking problems, a dramatic improvement in ROP and average cost/ft was achieved.
Design and Techniques of Testing and Evaluation of Deep Khuff Wells
Authors: Al Khatib M. A. , Sadik A. S. 
Published: December 2007

ABSTRACT
Three deep Khuff wells have successfuly been tested by ADCO. Formations tested were at 16,000-21,000 ft, where bottom hole temperatures and pressures reached 440°F and 0.64 psi/ft. The Khuff wells tested, the completion design needed for hostile service conditions, the testing techniques and the equipment used in stimulating and producing formation fluids at surface are described in this paper.
Formation, Distribution, and Prediction of Stylolites as Permeability Barriers in the Thamama Group, Abu Dhabi
Authors: Burgess C. J. , Peter C. K. 
Published: December 2007

ABSTRACT
Stylolites and associated pressure dissolution phenomena are common features of most carbonate reservoirs but their effects on reduction of porosity and permeability are variable. In chalky limestones such as the Thamama Group of Abu Dhabi stylolites may cause a reduction in permeability sufficient to create a barrier to fluid movement.
Most stylolites result from dissolution of carbonate as a result of overburden pressure. Dissolution occurs along pre-existing surfaces within the rock and in particular along bedding planes. The presence of even small amounts (&lt;1%Rv) of clay material in the rock encourages stylolite development. Thus in a sequence of uniform, laterally persistent lithofacies such as occur in the Thamama II and IIIa zones, stylolites may be similarly distributed and form field-wide vertical permeability barriers. In view of the relationship between stylolites and depositional lithofacies, prediction of their distribution may be made by core and log study and depositional modelling.
In an Offshore Abu Dhabi field, an attempt has been made to predict vertical permeability through stylolite zones in uncored wells. Comparison of the stylolite intensity index, calculated from FDC/CNL logs following the method of Johnson and Budd (1), with measurements from whole core and plug analyses showed that a statistically valid relationship exists between these two parameters. Separate relationships have been established for stylolites above and below the oil/water contact as values in the water zone tend to be further reduced by continued cementation. The establishment of these relationships has enabled the prediction of vertical permeabilities through stylolite zones in uncored wells. Vertical permeabilities of less than 1md equate to a stylolite intensity index of 50, and in the subject field such zones are likely to severely limit fluid movement. Such geological analysis can thus provide a useful model for aiding reservoir simulation and field development.
An Overiew of In-Situ Methods for Determining Remaining Oil Saturations
Authors: Blackwell R. J. 
Published: December 2007

ABSTRACT
This paper reviews the relative advantages and disadvantages of the following methods for measuring the remaining oil saturation (ROS): pressure coring, sponge coring, the single-well tracer method, and PNC, C/O, electric, EPT and NML logging methods. Careful planning and execution by well-trained personnel is considered mandatory for the field application of these methods.
Skin Effect and Completion Options in the Ras Budran Reservoir
Authors: Harper T. R. , Moftah I. 
Published: December 2007

ABSTRACT
High positive skin factors were encountered in early production wells drilled in Unit I of the Nubian Sandstone reservoir of the Ras Budran oil field. Laboratory tests and theoretical analyses were conducted, from which it was concluded that the observed skin factors could not be explained by conventional formation damage mechanisms. Alternative mechanisms are proposed, based upon the presence of low permeability quartz-filled fractures. These give rise to a heterogeneity. Types of completion potentially able to improve well productivity are identified.
Stimulating Very Long Gross Intervals
Authors: Blinten J. S. , Aziz R. M. 
Published: December 2007

ABSTRACT
Conventional acidizing and fracturing techniques are not applicable when very long gross intervals on the order of 1,000 to 3,000 feet are to be stimulated. Concepts such as fracture length and improved wellbore radius have little meaning in such cases since it is very difficult to predict or control the placement of stimulation fluids. Good diversion of fluids is the controlling factor for successful stimulation of very long gross intervals. The problem is compounded when long net intervals on the order of 500 to 1,000 feet are to be stimulated within these very long gross intervals. In such cases, the surface injection pressure required for conventional limited entry techniques can be prohibitive. These problems often can be solved by stimulating with high injection rates, buoyant ball sealers, and limited perforations.
Amoco Sharjah Oil Company has encountered these problems in attempting to stimulate the Thamama in Sajaa Field. A brief history of Amoco's experience in Sajaa Field with mechanical isolation and various diverting agents is presented. To date, 6 wells have been stimulated by using high injection rates, buoyant ball sealers, and limited perforations. Some of these jobs have contained the largest fluid volumes ever injected in the Middle East and at the highest rates attempted. The results of this technique have been encouraging. The job design, equipment requirements, fluid formulations, and results of these stimulations will be presented.
Horizontal Wells Production Techniques in Heterogeneous Reservoirs
Authors: Giger F. M. 
Published: December 2007

ABSTRACT
Two advantages of oil production with horizontal wells are the increase in productivity of each well and a new approach to solving reservoir-engineering problems resulting from heterogeneities. The aim of this paper is to propose elements of analysis focusing on flowline patterns and pressure distribution in an oil field. These elements should be of help to decision-makers when faced with an economic choice between spudding vertical or horizontal wells and eventually fracturing them.
Increasing Casing Collapse Resistance Against Salt-Induced Loads
Authors: Khalaf F. 
Published: December 2007

ABSTRACT
Casing collapse opposite Salt formations is a real field problem. Several solutions are proposed for this problem. This paper presents an analysis of three of these solutions, namely thick-walled pipe, high collapse resistance casing and multiple strings packed with cement. The strength of each solution and its effects on the drilling and completion practices are also discussed. The mechanical resistances to uniform and point loads of the multiple strings and thick walled pipe are superior to those of a high collapse solitary string.
The Tazerka Floating Production, Storage, and Offtake System
Authors: Ballard P. G. 
Published: December 2007

ABSTRACT
Production from small oil reserves found offshore which would be uneconomic on the basis of a conventional approach have been developed by utilising a Floating Production Storage Unit permanently moored to the seabed by a Single Anchor Leg System. The storage unit not only supports the production facilities but also acts as the offshore terminal, thus offsetting the cost of a pipeline and shore terminal. In addition to the use on small reservoirs, a similar installation may also be utilised for the early production of large offshore oil accumulations and in both cases, retains the advantage that a major part of the investment can be redeployed elsewhere when the field has been exhausted or permanent facilities have been installed.
This paper describes a system installed offshore Tunisia by Shell Tunirex but unlike other floating production systems, it has the capability of tying in several sub-sea completed wells. In addition, it has the flexibility to cater for additional wells or functions, such as gas lift or water injection, should they be required to optimise oil recovery later in the field's life.
Core-Annular Oil/Water Flow: The Turbulent-Lubricating-Film Model and Measurements in a 2-in. Pipe Loop
Authors: Oliemans R. V. A. , Ooms G. , Wu H. L. , Duijvestijn A. 
Published: December 2007

ABSTRACT
Core-flow tests with a 3000 mPa.s fuel oil in a 2-inch test facility have revealed important information on the amplitudes and lengths of waves at the oil/water interface. The wavelengths vary considerably with water fraction and oil velocity. Moreover, the flow in the water annulus is turbulent. A previously developed theoretical model for steady core-annular flow in pipes has been extended by incorporating the effect of turbulence in the water film surrounding the oil core. Core-flow pressure gradients predicted by the adapted model coincide very well with measurements provided that actual wave amplitudes and wavelengths observed during these tests are used as input data.
Utilisation of Gas Resources in Qatar: A Decade of Planned Development and Integration
Authors: Ferdrin J. P. 
Published: December 2007

ABSTRACT
Qatar's demand for energy has increased tremendously during the last decade due to expanded economic activity since the early 1970's and subseguent diversification through development of downstream industries. Most of the energy requirement is met by natural gas.
The purpose of this paper is to describe the development of a gas oriented producing country and the operating philosophy for maintaining maximum efficiency and preserving the Nation's natural resources.
Debottlenecking of Acid Gas Removal Units
Authors: de Fraissinette C. , El Komy O. F. , Piquet F. 
Published: December 2007

Abstract
The Abu Dhabi Gas Liquefaction Company (ADGAS) has since 1977 operated the only gas liquefaction plant in the Middle East producing simultaneously LNG, LPG and Pentanes. The Plant processes the associated gases from Abu Dhabi offshore oil fields as well as non associated gas. This is the only LNG facility in the world operating on associated gas.
The gas composition of the 11 different feed streams supplying the LNG plant varies broadly and for instance the sour gas content (CO2+H2S) of each stream can vary between 3.3% and 34%. An average gas stream composition supplied to the Acid Gas Removal Unit is given in Table-1.
The Plant consists of two identical process trains in parallel arranged to permit safe overhaul of one train while the other remains in service.
Conception and Construction of an LPG Tank Using a Composite Membrane Technology
Authors: Fuvel P. , Claude J. 
Published: December 2007

ABSTRACT
TECHNIGAZ and TOTAL C.F.P. have developed a new LPG storage technology derived from the membrane concept used for LNG storage and transportation.
This technology called GMS uses a composite membrane as primary barrier. A 2 000 m3 storage pilot unit, based on that concept, is under construction in TOTAL'S refinery at DUNKIRK (France) since September 1983.
Offshore Refrigerated LPG Loading/Unloading Terminal Using a CALM Buoy
Authors: Bonjour E. L. , Simon J. M. 
Published: December 2007

ABSTRACT
In existing Liquefied Petroleum Gases terminals, the transfer of liquefied gases to the tanker is performed via articulated loading arms or flexible hoses, working under quasistatic conditions. The tanker has to be firmly moored alongside a jetty or a process barge in a protected area (such as a harbour in most cases).
This paper gives the main results of the development of an offshore refrigerated LPG (−48° C) loading / unloading system, using a CALM buoy and LPG floating hoses working under dynamic conditions. The aim of this new concept is to replace the standard harbour structure for loading /unloading refrigerated LPG and to provide: –a considerable reduction in investments;–a greater flexibility regarding the terminal location.
The main components of that terminal have been designed so as to enable the loading of a 75 000 cubic meter LPG carrier in 15 hours. The results of static and dynamic low temperature tests on a LPG swivel joint for CALM buoy and LPG floating hoses show that such a SPM terminal is now a realistic solution.
Formation Damage Prevention through the Control of Paraffin and Asphaltene Deposition
Authors: Newberry M. E. , Barker K. M. 
Published: December 2007

ABSTRACT
Formation damage caused by the precipitation and deposition of paraffin or asphaitene particles has been a recurrent problem in the production of crude oil.
A number of well established oilfield operations have been found to aggravate these organic deposition problems. Laboratory testing of crudes and chemical additives has led to a number of solutions to these problems. Case history information on testing, chemical application, and subsequent field results are presented.
Parameters Affecting Fracture Design and Their Measurement During Treatments
Authors: Pearson C. M. , Abou-Sayed I. S. , Nguyen N. B. 
Published: December 2007

ABSTRACT
This paper shows how an understanding of the relative influence of fracture design parameters, and treatment procedures enable the engineer to improve hydraulic fracture results. The measurement of a few critical parameters provides a better understanding of fracturing in a particular formation.
Results are presented from a joint program of research carried out between Gulf Research & Development Company and Gulf Oil Exploration and Production Company during 1984. The principal objectives of this program were to obtain improved field data for the verification of fracture simulators, and to investigate the field measurements and analysis of parameters found to significantly affect design. Emphasis is placed on understanding the effect of reservoir properties on the created fracture and the required fracturing pressure. This information was then used in the field to optimize limited size treatments in particular formations.
Pressure Fluctuating Tool
Authors: Payne R. A. , Williams K. A. , Pelty L. L. , Bailey H. L. 
Published: December 2007

ABSTRACT
The Pressure Fluctuating Tool (PFT) utilizes a fluidic oscillator to create pulsating pressure for breaking down perforations. The maximum pressure fluctuations produced by the oscillator can be as great as 1500 psi (10,300 kPa) above and below downhole ambient pressure with frequency ranging from 140 to 160 cycles per second. Pressure fluctuations are greatest in the primary oscillation zone located at the center of the 26 foot.(7.92m) long tool. The pressure fluctuations decrease to essentially zero within 8 feet (2.43m) above and 8 feet (2.43m) below the primary oscillation zone. These fluctuations break down the perforations and formation face.
As perforations are opened, the casing annulus is effectively exposed to a larger fluid volume, causing the amplitude and frequency of fluctuations to decrease. These changes are monitored by instrumentation at the surface to determine when breakdown is complete and the tool can be moved to the next section of perforations.
This paper will describe the operation of the PFT and report data collected in field applications.
Electrical Submersible Pump Performance Using Variable Speed Drives
Authors: Wilson B. L. , Liu J. C. 
Published: December 2007

ABSTRACT
Variable speed drive units (VSD) designed specifically for use with electrical submersible pumps (ESP) have been available for several years. The ability to vary the operating speed of the ESP greatly expands the operating range of the unit. To take full advantage of the capabilities of an ESP operating on a VSD, it is necessary to understand the concepts of sizing and the operational limitations of the equipment.
Tubing Protection and Design for Corrosive Environment
Authors: Hayatdavoudi A. , Altunbay M. 
Published: December 2007

ABSTRACT
Present methods of corrosion mitigation, although successful and advantageous over past methods, appear to be highly overdesigned and thus prove to be expensive.
In order to reduce the cost of corrosion control, the authors have proposed a series of calculation steps that limit the corrosion control to specific intervals of tubing rather than the whole string of tubing. Further cost saving measures can be realized by completing the corrosive wells with a system that monitors corrosion and regulates the mass flow rate of inhibitor into the tubing automatically.
Field Investigation Identifies Source and Magnitude of Iron Problems
Authors: Gougler P. D. , Hendrick J. E. , Coulter A. W. 
Published: December 2007

ABSTRACT
Recent field studies indicate that iron may be a problem in acid stimulation, even in formations that do not contain iron minerals. A program was undertaken to identify the sources of iron that may be carried by fluids used in well stimulation. While possible sources have been suggested by many investigators, this program was conducted on well sites where acid was pumped out of typical steel tanks, through conventional blending and treating equipment and well tubulars. Sources of iron encountered were identified by monitoring at multiple points in the process. A surprisingly high concentration of iron was found in the first portion of the acid passing through the system.
New Conductivity Found in Angular Blends of Fracturing Sand
Authors: Larsen D. G. , Smith L. J. 
Published: December 2007

ABSTRACT
Recent tests have shown that the conductivity of a 20-40 sand pack is increased by blending angular sand with the very round product currently used in hydraulic fracturing. The oil and gas industry requires fracturing sand to meet high roundness specifications, according to the Krumbein and Sloss chart, for the purpose of providing the optimum geometric pack in the fracture. Indeed this will decrease point pressure on the sand grains and reduce crushing and fines generation in the sand pack, but tests indicate that the optimum geometric pack for crush resistance does not always offer the maximum conductivity through a sand pack.
Sand grains with a roundness factor of .5 (the minimum API standard for frac sand is .6) were mixed in 50/50, 62.5/37.5, 75/25, 87.5/12.5 and 100/0 blends with sand grains having a roundness factor of .8. These combinations were placed in a conductivity cell and tested at closure stresses as high as 10,000 psi. Several blends proved more conductive than the 100% highly rounded grains used as a control sample. This paper will show how the increased void space of a round-angular sand combination overcomes its susceptibility to crushing and provides increased conductivity, the most reliable measurement of a sand's overall performance.
Optimization of Fracture Fluid Recovery and Production Through the Use of a New Stimulation Technique
Authors: Phillips A. M. , Wilson W. J. 
Published: December 2007

ABSTRACT
A technique for improving stimulation fluid recovery has been developed in the laboratory and has proven effective in field applications. The method involves improving proppant pack drainage and minimizing capillary pressure in the formation through the judicious application of surface active agents.
The technique is particularly applicable in low pressure oil wells and tight gas reservoirs, and may be used in all aqueous fracturing treatments. These include slick and gelled water, as well as foamed and crosslinked systems. The technique involves the use of a solvent in the pad fluids and a surfactant system throughout the entire fracturing treatment. This combination improves sand pack drainage and minimizes capillary water blocks in the invaded formation, while maintaining the water-wet condition of both the proppant pack and formation.
The results of field applications using this technique have shown great improvement in the recovery of aqueous stimulation fluids in both sand and limestone formations. Increases in initial hydrocarbon production have also resulted. Case histories are presented from both oil and gas wells in a variety of formations.
Successful Stimulation of the Olmos Formation Using Oil-Base Fluids and High-Proppant Concentrations
Authors: Pauls R. W. , Venditto J. , Chisholm P. , Holtmyer M. , Gregorcyk W. 
Published: December 2007

ABSTRACT
Successful stimulation of the Olmos Formation in McMullen County, Texas, has proven to be challenging. Initial attempts at fracturing the Olmos using water-base fluids and low proppant concentrations did not prove to be very successful. Core studies have indicated this formation to have a fluid retention tendency. Gelled hydrocarbon fluids with high sand concentrations are now being used as a fracturing system with significantly improved success.
The transition to gelled oils capable of carrying high sand concentrations has presented some unique challenges to the industry because portions of the Olmos Formation are at depths approaching 10,000 ft [3050 m] with bottomhole temperatures to 259°F [126°C]. The most successful fracturing treatments in the Olmos appear to result from long fractures propped with high concentrations of propping agent. The long fractures contact additional reserves and the high sand concentrations not only produce highly conductive fractures but also settled bank heights capable of filling the fracture below and through the Olmos zone. Fluid viscosities required for these treatments were based upon pre-fracturing analyses and computer evaluations, which determined fluid efficiency and fracture closure times. This posed a problem as the commonly available oil-based fracturing fluids either did not have sufficient fluid viscosity downhole over extended periods at high temperature (at least six hours at 259°F [126°C]) or, if they did meet this requirement to place the proppant, were too viscous on the surface into which high concentrations of sand could be mixed or be easily handled with surface equipment.
To date, in excess of 60 wells in the Olmos have been treated successfully using high sand concentrations and a new method for gelation of oil-base fluids. This method involves use of enough gelling agent to gel the hydrocarbon for the required surface viscosity and downhole stability, and also provide the needed amount of activator for surface conditions. The activator concentration can be varied to produce a base gel which is easily pumped and into which the propping agent can be easily mixed. As this base gel is being pumped downhole, additional activator is added to produce a gelled fluid needed for downhole conditions. Treatments in the Olmos have evolved up to 1,800,000 pounds [816,500 Kg] of 20/40 mesh Ottawa sand and 250,000 gallons [946 m3] of gelled fluid. Jobs are pumped at 12 bbl/min [114 m3/sec] for up to 10 hours, averaging 12 lb of sand/gal of fluid [1400 Kg of sand/m3 of fluid] with a maximum concentration of 17 lb of sand/gal of fluid [2000 Kg of sand/m3 of fluid]. The wells so treated have responded with more sustained production than wells treated with less temperature stable fluids containing lower concentrations of sand.
Laboratory studies, treatment methods, completion and production data will be presented.
Computer Graphics-Aided Systems Analysis: Application to Well Completion Design
Authors: Detamore J. E. , Sharma M. P. 
Published: December 2007

ABSTRACT
The development of an engineering tool (in the form of a computer model) for solving design and analysis problems related with oil and gas well production operations is discussed. The development of the method is based on integrating the concepts of "Systems Analysis" with the techniques of "Computer Graphics". The concepts behind the method are very general in nature. This paper, however, illustrates the application of the method in solving gas well completion design problems. The use of the method will save time and improve the efficiency of such design and analysis problems. The method can be extended to other design and analysis aspects of oil and gas wells.