bluuebunny/crossref_metadata_2025_split huggingface dataset:
The Economic and Operational Results of the Long-Term Stackout of a Land Rig
Authors: Holm D. W. 
Published: December 2007

ABSTRACT
The principle purpose of this paper is to evaluate the effects of long term land rig storage on the economics of returning a rig to service and the operational performance that may result.
This evaluation includes an example, with discussion, of the actual results of returning a stacked rig to service.
The paper discusses the general procedures and costs associated with the initial preservation of the rig, the preventive maintenance required to maintain the rig while stacked, a description and cost of the work required to return the rig to service, and the performance of the rig in the field in terms of downtime.
Problem areas of land rigs stacked on a long term basis are reviewed.
The paper concludes with a discussion of what can be expected of rigs that have not been properly preserved and/or prepared for return to service.
Survival Craft Training for the Offshore Industry
Authors: Lund G. L. , Zambon F. 
Published: December 2007

ABSTRACT
As a result of marine disasters in the Offshore Petroleum Industry, there has been an increased emphasis on the training of marine safety. The U.S. CoastGuard has proposed licensing requirements for the Mobile Offshore Drilling Units (MODUs) that will mandate training in the enclosed lifeboat (covered powered survival craft) and survival suits. An analysis will be made of the traditional training currently implemented, international standards of training, recently proposed Coast Guard required training, and how to determine task analysis for this type of training. We will look at methods of validating objectives and training along with the practicality of hands on training with actual equipment in the work environment versus simulation. The relationship of formal training and the currently required drills will be discussed and how they can effectively complement each other. The methods of research included historical evidence, behavioral studies into training, current recognized standards of training, and field surveys. Also, a case study using a pre-test, and a random selected subgroup for a performance re-test will be analyzed. The study identifies needed training and concludes that the emphasized principles of instruction should be: a simple presentation; the concentration on fundamentals; the minimization of lecture; and the provision of hands-on practice. Safety limitations will dictate how realistic any training can approximate the actual tasks and conditions to test the students skills. A combination of actual and simulated hands-on exercise along with classroom instruction will optimize the learning procedure. For maximum retention formal training should be reinforced with regularly scheduled drills and instruction at the work site. Feedback isthe key to analyzing the effectiveness of the training.
Bit Balling in Water-Reactive Shale During Full-Scale Drilling Rate Tests
Authors: Cheatham C. A. , Nahm J. J. 
Published: December 2007

ABSTRACT
This paper demonstrates a useful means of studying bit balling in laboratory drilling tests. Full-scale tests were conducted using a new 6-1/8 in. (156 mm) tricone insert-type bit, realistic muds, and Pierre shale, which is similar to water-reactive shales which are apt to cause balling in the field. Balling ranged from slight to severe with an uninhibited water-base mud, and did not occur with an oil-base mud. The ratio of bit torque to weight-on-bit was a reliable indicator for detecting the degree of balling. The results show that proper modeling of bit balling in the laboratory must address the degree of overbalance which results from insufficient mud weight in the field. They also indicate that increasing mud weight, in the field is an effective means to reduce or prevent bit balling if, and only if, balling is caused by mechanical (not chemical) wellbore instability. Although bit balling would become (irreversibly) severe within seconds, it could be prevented by significantly reducing weight-on-bit quickly enough after incipient balling.
The Development of the Furrial Field with Innovative Drilling Framed Within the Philosophy of Improvement of Quality of Work
Authors: Perez F. E. , Sanguino J. E. , Cumana J. 
Published: December 2007

ABSTRACT
Since the completion of the first exploratory well in 1986 until June of 1989, LAGOVEN has put on stream a total of 15 wells averaging a daily production of 100.000 BPD of medium API gravity oil in this 32.000 acres field. To drill these deep, high pressure, high temperature wells, a series of tecnnological innovations has "been introduced which have allowed us to reduce the drilling time from 24 days/1000 ft to 4*7 days/1000 ft, averaging lately a drilling cost of 358 $/ft which is 40% lower than the world's average of 592 $/ft.
To reach this goal, LAGOVEN has developed and adapted several techniques and operational practices, together with a project directed to create the optimum drilling organization all framed within the scope of the philosophy of improvement of quality of work. Among the most important ones we could mention: the creation of a task force to manage the drilling project, adjustments in the designs of surface locations, well heads, drill and casing strings, hit, muds, cement, perforating guns and the implementation of dual completion systems.
The objetive of this work is to describe the evolution of the drilling activity as well as of the human resources that has allowed LAGOVEN to develope The Furrial field in a very optimized manner, by applying the philosophy of improvement of quality of work.
Cement Spacer Fluid Solids Settling
Authors: Moran L. K. , Lindstrom K. O. 
Published: December 2007

ABSTRACT
In recent years emphasis has been placed on the use of "turbulent flow" spacers. Normally this practice helps in obtaining higher drilling fluid displacement efficiencies, and thus a good cement job. However, depending on placement rates, well geometry, etc., the solids required in these relatively thin spacer fluids can settle even in dynamic conditions. This problem is manifested in deviated wells by a channel of solids forming on the low side of the pipe and annulus. This channel of solids prevents placement of a continuous cement sheath in the annulus, providing a potential path for interzonal communication.
To develop a better understanding of this phenomenon, a full scale laboratory investigation was conducted using field mixing equipment and a large scale, simulated wellbore test facility. Factors evaluated for their influence on spacer settling included (1) various pipe geometries, (2) pipe centralization, (3) fluid rheological properties and composition, (A) flow rates, and (5) well deviation angles. As a result of this investigation a mathematical correlation was developed to predict minimum flow rates required to alleviate spacer solids settling in highly deviated wells. It is apparent from these test results, that achieving turbulent flow is not the sole criterion for obtaining optimum spacer efficiency. This paper presents test procedures, equipment descriptions, and discussion of results, in addition to a full definition of the problem of spacer settling.
Adsorption Characteristics of PHPA on Formation Solids
Authors: Liao W. A. , Siems D. R. 
Published: December 2007

ABSTRACTOne of the most important uses for polymers in drilling fluids is shale stabilization. The shale stabilizing mechanism is not very well understood, but many think it results from hydrated polymer molecules interacting with water and shale surfaces by a process of adsorption. Adsorption is a complex surface phenomenon. Measurement of solution viscosity may not be adequate to quantify the adsorption characteristics of polymers. This study focuses on the static adsorption of a partially hydrolyzed polyacrylamide polymer (PHPA) on formation solids. The study also investigates various factors affecting adsorption of polymers. The adsorption was quantified by adsorption density, which is the amount of polymer adsorbed per unit surface area of solid particles. Application of laboratory findings to field situations is also discussed.
The Development of an Inhibitive Cationic Drilling Fluid for Slim-Hole Coring Applications
Authors: Beihoffer T. W. , Dorrough D. S. , Schmidt D. D. 
Published: December 2007

ABSTRACT
This paper describes a new inhibitive cationic drilling fluid developed for slim-hole coring applications. High rotational speed slim-hole coring requires a drilling fluid that will maintain a gauge hole to preserve the bearing-like tolerances between the drillstring and wellbore. A low-solids fluid is also required to prevent drill solids from centrifuging inside the drillstring. This paper describes both the laboratory development and field testing of the drilling fluid.
Conventional water-based drilling fluids rely on dispersed clay for viscosity and fluid loss control. Negatively charged (anionic) materials are often added to the fluid to inhibit reactive shale formations. In this study, additives with a positive charge (cationic) were investigated as shale stabilizing agents.
The study found that quaternary ammonium salts (cationic surfactants) gave high recoveries in the shale rolling test. The ability of the surfactants to stabilize shale was found to vary with chemical structure. Despite their ability to stabilize shale, the surfactants were unsuitable for use in drilling fluid formulations because of their tendency to foam. Low-molecular weight synthetic cationic polymers that contain structures similar to the surfactants gave shale recoveries as great as the surfactants but without the foaming problems. The combination of potassium chloride with cationic polymer resulted in shale recoveries greater than with either component alone.
Drilling fluids were formulated based on a combination of a cationic polymer and KCl. Initial work indicated that many commercially available drilling fluid additives were incompatible with the cationic polymer. Additives were found that were compatible and provided satisfactory drilling fluid properties. Field testing of a cationic/brine drilling fluid suggested that the fluid was highly inhibitive when compared to close offset wells drilled with conventional water-based drilling fluids. The fluid was compatible with the slim-hole high rotational speed coring system.
Material Balance Concepts Aid in Solids Control and Mud System Evaluation
Authors: Dearing H. L. 
Published: December 2007

ABSTRACT
Evaluation of the entire system of solids control equipment and control techniques and the mud system can be accomplished by using several simple concepts and understanding their interrelationship. The concepts of solids removal efficiency, mud usage, and equilibrium drill solids can be related together with a simple equation. These concepts are used to post analyze wells, illustrating typical drilling fluid and solids control problems. Solutions are suggested with quantified results needed for economical applications.
Downhole Gas Detection Method in Drilling Fluids
Authors: Vestavik O. M. , Aas B. , Podio A. L. 
Published: December 2007

ABSTRACT
Gas entering the well during drilling operations may often lead to expensive well problems and can sometimes lead to disastrous blowouts. In order to find improved methods for early detection of gas, the possibility of using an acoustic interferometer has been investigated. This work shows that interferometric measurements are very sensitive to the presence of free gas in liquids. The acoustic interferometer has the potential to become an effective method for the early warning of gas while drilling. It would be especially valuable when drilling in areas with shallow gas zones. The interferometer is judged to be applicable for MWD.
Environmental Directionality Considerations in MODU Location Assessments
Authors: Malcolm B. G. , Cowgill C. F. 
Published: December 2007

ABSTRACT
The effects of considering environmental directionality in the assessment of Mobile Offshore Drilling Unit (MODU) locations are examined in this paper. A specific North Sea jack-up location is reviewed.
Traditionally, the suitability for operation of a MODU at a given location is determined by simultaneously applying the maximum design wind, wave, and current values simultaneously from the worst possible directions for assessing stresses, overturning moments, etc. These environmental loads are treated as a quasi-static load case. Stresses, overturning moments, and preload requirements resulting from this extreme load case are estimated and compared to design allowables.
Many site-specific assessments are now beginning to include second-order effects and are also attempting to evaluate the dynamic responses of MODU's. Peak static loads and peak dynamic loads do not necessarily occur simultaneously. The possibility of overly conservative load and stress predictions exists if an extreme environment is simultaneously applied from the worst directions in these evaluations.
An argument for considering rig orientation and environmental directionality is presented. Results obtained from a directionality assessment are reviewed. It is concluded that site assessments based on environmental directionality considerations are a reasonable and prudent indicator of safe MODU locations.
Drilling With Semiautomatic and Automatic Horizontal Racking Rigs
Authors: Deguillaume J. , Johnson B. 
Published: December 2007

While ELF has started exploration under the city of Paris, the Paris Basin remains the area of FRANCE where the activity is relatively important with the most promising recently discovered oilfields.
The high drilling activity during the years 84 to 86 in the Paris Basin area of France has led to a significant optimization of all operational conditions for realizing medium depth wells (between 6000 ft and 9000 ft). It was possible by improving drilling factors as bits, mud and directional drilling but also by the strong development of turnkey and incentive day rate contracts and the introduction of semi-automatic and automatic rigs. New concepts, mechani-zation and automatization are more than ever a must to enable drilling to take place in an urban environment. At the same time, automatization of rigs will increase work safety and also reduce cost footage.
Two new rigs were introduced for realizing wells with a lightened 6" "slim hole" drilling programme to a T.D. of 6000 ft to 8000 ft : their names are FORAMATIC 1 (end of 84) and FORAMATIC 2(end of 85).
At these depths the FORAMATIC 1 and 2 not only give the advantages of reduced crews, less civil engineering and environmental impact, increased safety and good drilling performance but significantly decrease the cost of drilling a well.
This paper gives a technical presentation of both rigs, after reminding machineries which have been built with similar concepts. Advantages and drawbacks of FORAMATIC rigs are brought out by considering field performances and procedures in Paris Basin area. Special attention is beared on the FORAMATIC 2 rig where automatic tripping is possible and a real time data monitoring has been developed.
A New History-Matching Technique in Simulating Steam Injection Projects
Authors: Ying A. N. , Dougherty E. L. , Wang S. W. 
Published: December 2007

ABSTRACT
As previously reported1,2,3, a scaled physical model was developed to study the oil recovery efficiency of steam injection into horizontal wells. Experimental performence evaluations were made with two types of synthetic oils with injection of steam at different qualities. In this paper, the results of these laboratory studies are compared to predicted performance using a three-dimensional, three-phase thermal simulator.
Previously, most history matching studies have relied heavily upon adjustments to the relative permeability curves to obtain agreement between calculated and observed production data. In this study, to match production data we devised a new technique in which at elevated temperatures oil viscosity is lowered and water viscosity is increased so as to converge to a common value at steam temperature. Conceptually, this technique implies that at steam temperature oil and water tend to form as a combined emulsion phase. The presence of an emulsion phase is evidenced by experimental studies and thermal oil production in the field.
We successfully used the proposed technique to match the oil and water production data obtained from laboratory experiments. The efficacy of the technique demostrated by comparing observations to three separate prediction runs; (1) base case using standard relative permeability and viscosity data (2) results computed with only relative permeability adjusted, and (3) results with only viscosity adjusted. The history matching studies include oil production from vertical wells in a five-spot pattern and horizontal wells in a trench pattern.
Appraisal of Analytical Steamflood Models
Authors: Chen H-L. , Sylvester N.D. 
Published: December 2007

Abstract
Steamflooding in heavy oil reservoirs is one of the principal thermal oil recovery methods. This paper evaluates principal thermal oil recovery methods. This paper evaluates the existing analytical steamflood models with respect to their mechanisms and predictive capabilities and compares them with field data. The three steamflood models selected were: a frontal advance model [Jones (1981)], a modified frontal advance model [Farouq Ali (1982)], and a vertical gravity override model [Miller and Leung (1985)]. Each model was somewhat modified to improve its ability for the prediction of production rate and/or history match of typical field production rate and/or history match of typical field production data. production data. The Jones steamdrive model, with its empirically determined scaling factors, was found to give a reasonable history match of oil production for the Kern River field. Fields with different characteristics will require an adjustment of these scaling factors and/or field property data to achieve an acceptable history match. The modified Farouq Ali steamdrive model gives a good history match without need for empirical factors or adjustable parameters. It is thus recommended for the prediction of steamdrive oil recovery when field production data are unavailable. The Miller-Leung gravity override steamflood model, which contains two adjustable parameters, was found to possess the best overall history matching Capabilities and is recommended for this purpose. purpose.

Introduction and Literature Review
The injection of steam into heavy or pressure depleted oil reservoirs has been a successful enhanced oil recovery process for more than three decades. A principal application process for more than three decades. A principal application of the steam injection is steamflooding which is also termed steam drive or steam displacement. In this process, steam is continuously injected into a number of injection wells, and the displaced fluids are produced from the production wells. Ideally, the injected steam forms a steam saturation zone around the vicinity of the injection well. The temperature in the steam zone is nearly equal to that of the injected steam. Moving away from the injection well, the steam temperature drops gradually as the steam expands in response to the pressure drop and heat losses to base formations. At a certain pressure drop and heat losses to base formations. At a certain distance, the steam condenses and forms a hot-oil bank. In the steam zone, oil is displaced by the steam. In the hot oil zone several changes take place which result in oil recovery. They include heat losses the formation, thermal expansion of the oil, and reduction of oil viscosity. In addition, residual saturation may decrease and changes in relative permeability may occur due to the variations of temperature and saturation.
The Effect of Surface Phase Splitting on Project Oil Recovery
Authors: Hazlett W. G. , Mims D. S. , Walzel M. D. 
Published: December 2007

ABSTRACT
This paper presents the results of an investigation of the effects of surface phase splitting and project interaction on oil recovery. The study utilized a multi-pattern, generic model with typical Kern River reservoir properties. The major result of this study is that surface phase splitting within a homogeneous, preheated, nine pattern project does not appear to have significant effect on either oil production rate or cumulative oil production. In addition, oil recovery within a particular project was shown to be greatly affected by neighboring projects.
Performance Correlations for Steamflood Field Projects
Authors: Torabzadeh S. J. , Kumar M. , Hoang V. T. 
Published: December 2007

ABSTRACT
Actual steamflood field performance data show that the shape of the oil recovery curves is generally different from simple predictive models that are currently used, such as Gomaa's correlation (which is based on symmetric element simulations) or analytical models. This paper presents a method and shows how actual field data can be used as a more accurate predictive and diagnostic tool. It was found that normalized oil recovery (fraction of mobile oil-in-place) vs. steam injection (heat injected/ volume or pore volume cold water equivalent) provides a uniform basis to compare and evaluate different projects quantitatively.
Normalized performance histories for various projects in the same field were similar, indicating that histories of previous projects can serve as a preliminary predictive tool for future projects. The normalized curves were correlated with reservoir parameters and operating conditions, using a stepwise, multiple-variable, linear regression method. A new procedure was developed and correlations were obtained for the data in this study. However, no single correlation could be found for all projects. Improved correlations were obtained when the projects were subdivided into two groups, based on predominant production mechanisms.
Large-Scale Facility Expansion Evaluations at the Kuparuk River Field
Authors: Weiss J. L. , Masino W. H. , Starley G. P. , Bolling J. D. 
Published: December 2007

Abstract
Decisions concerning future development options at the Kuparuk River Field are complex and interrelated. Various development strategies are being evaluated. To help address these issues, a facilities model has been added to a full field reservoir simulator. Facility limits are used with a well ranking system to shut in marginal production when equipment capacity constraints are exceeded. The model simulates field operating strategies which maximize production. Operational strategies are modelled using (1) a wellbore hydraulic routine that enables bottom hole pressures to change (reflecting the benefit of various gas lift rates), (2) a gas lift allocation correlation that was determined from field data, and (3) a gas management routine which optimizes oil production while honoring gas capacity constraints and field gas lift needs. These gas management and hydraulic features are essential to properly evaluate future projects in a gas capacity constrained environment and can be applied to other reservoir simulation tools. An example of how the reservoir simulator is being used to address a key issue in the large scale facility expansions evaluation is included.