bluuebunny/crossref_metadata_2025_split huggingface dataset:
The Development of Automated Drilling Rigs
Authors: Reid David 
Published: December 2007

Abstract
Handling tools have been improved and adapted, wherever possible, to aid remote automation on today's drilling rigs. Work that was done manually using elevators, spinning chains, tongs and brute force is now managed by using remotely controlled machines.
The application of automation to improve the performance of drilling rigs has captured the attention of the drilling industry for years. Numerous rig designs have been tried with relatively few success stories. The history of drilling automation can be paralleled to the development of Pipe Handling Systems on the drilling rig floor.
This paper offers examples to support the theory that there are four critical developments required to achieve automation on the drill floor.
P. 695
Hybrid Coiled Tubing System for Offshore Re-entry Drilling and Workover
Authors: Selby Bruce , Srinivasan Nagan , Donnally Bob , Vincent Randy , Wilke Jerry 
Published: December 2007

Abstract
In coiled tubing offshore re-entry drilling and workover operations, a jack-up pulling unit or an independent mast has traditionally been used to pull pipe out of the wellbore before the coiled tubing services could be employed. This method of operation often becomes cumbersome and costly. An innovative coiled tubing (CT) drilling system that offers an alternative method to the conventional techniques has been introduced to the oilfield. The new system, the hybrid coiled tubing system (HCTS), integrates the coiled tubing injector, the power unit and the reel into a transportable rig with a mast.
The concept and design of the methods and equipment were developed to respond to the need for servicing shallow to moderate-depth oil or gas wells in the Gulf of Mexico. In this area, typical well specifications range to 10,000 ft measured depth; and wells are usually directionally drilled from multiple-well, fixed platform structures or in shallow inland waters.
A specific case history is outlined to show the utility of using hybrid CT instead of a conventional rig for the type of work required. Operational efficiency and safety advantages are evident in mobilization, demobilization, speed of rig-up and rig-down, and in the reduction of time needed for tripping into and out of the well.
This system provides a cost efficient solution to the need for a re-entry system for offshore use.
P. 23
Proactive Safety Approach for Well Construction in Alaska's Kuparuk River Field
Authors: Petrash D.M. , Graff A.O. , Trantham J.A. 
Published: December 2007

Abstract
In 1995, the Kuparuk Drilling Group (KDG) recognized that safety performance had continually improved since well construction commenced in the Kuparuk River Field in 1981. However, it was also recognized that performance improvement appeared to be losing momentum. Upon analysis of the trend, it was noted that most efforts to reduce workplace risk were focused on 1) engineering controls; 2) administrative controls and operating practices; and 3) personal protective equipment.
In order to return to improving safety performance, attain world class status, and help employees return safely from the workplace to their families, the KDG solicited input from the drilling contractor to develop and implement a proactive behavior-based safety program. Part of the development included a goal-driven incentive, the Safety Performance Goals Program, which de-emphasizes safety statistics and fully complements the overall safety objectives.
P. 771
New Facets of Universal Fluid Usage: Reduction of Hole Wash-Out and Solidification for Environmentally Safe Drilling Waste Disposal
Authors: Nahm J.J. , Wyant R.E. , Rask J.H. , Thant Myo , Cannon Gene 
Published: December 2007

Abstract
Two new benefits derived from the use of a Universal Fluid (UF) have been demonstrated:reduction of the hole washout volume andsolidification of excess drilling fluid and drill cuttings for environmentally acceptable on-site waste disposal.
A UF containing about 30 lb/bbl blast furnace slag was used as a drilling fluid while drilling a recent south Louisiana well in an effort to reduce hole washout and to demonstrate that the solidification of the UF and drill cuttings would provide an environmentally safe material which remains on-site and can be used for location maintenance, road construction, and land fill or other uses.
The UF was used while drilling a 9 7/8-in. hole from 3,125 ft to the casing depth of 10,600 ft. The slag content ranged between 25 and 30 lb/bbl, while the UF weight was increased slowly from 9.4 lb/gal to 12.2 lb/gal. Caliper logs indicated that the average diameter of the UF-drilled section was 10.88 in., considerably better than the 12.85 in. of the same section of a previously drilled offset well. Of the total 147,000 lb of slag used, about 30% remained in the UF, about 22% was deposited as filtercake, and about 21% was discharged with the cuttings through solids control equipment.
A concept of rig-site drilling waste management involving solidification of the UF wastes is elaborated and related lab and field data are presented. The necessary amount of slag for solidification is already in the UF and solid wastes, but additional slag can be added depending on the final product firmness desired. To demonstrate the waste solidification process, an additional 20 lb/bbl slag was mixed with a 40-barrel batch of the excess waste in a "V," -bottomed auger tank. The UF mixture was allowed to harden on location and successfully used for land fill. This paper shows that the UF can protect the drilled wellbore and can be economically treated and used for on-site disposal.
P. 785
Early Kick Detection Through Liquid Level Monitoring in the Wellbore
Authors: Schubert J.J. , Wright J.C. 
Published: December 2007

Abstract
Through the years many tools have been developed to detect kicks in their early stages, when they can be handled more easily and safely. However, most of these tools are dependent upon the well being full of fluid with the liquid at the surface. When drilling wells where there are severe lost circulation problems (e.g., no returns to the surface) many of the major kick detection tools do not function properly since the liquid level may be hundreds or thousands of feet below the surface. During tripping operations, the major kick indicator is measurement of the volume of drilling fluid required to "fill" the hole to replace the volume of steel removed. If the annulus cannot be filled, again due severe losses to the open formation, measurement of the fluid pumped into the annulus does not give meaningful information as to formation fluid influx until the influx is great enough to begin to unload the annulus.
This paper proposes the use of an acoustic device installed on the casing valve to continuously monitor the liquid level in the annulus of wells experiencing complete loss of returns. A rise in liquid level can be interpreted as an early indication of a kick during drilling or tripping operations. The liquid level can also be used to determine the correct volume of fluid to pump into the well while tripping out of the hole.
This paper presents the results of tests run using common acoustic tools to monitor the liquid level in the wellbore of an Austin Chalk re-entry. Results of these tests show that the liquid level can be accurately monitored during complete lost returns so that kicks can be detected early during drilling or tripping operations.
P. 889
New Insight into the Mechanisms of Shale Inhibition Using Water Based Silicate Drilling Fluids
Authors: Bailey L. , Craster B. , Sawdon C. , Brady M. , Cliffe S. 
Published: December 2007

Abstract
There has recently been a resurgence in the use of water based muds containing sodium silicate for drilling reactive shale sections, particularly in the North Sea. The performance of these silicate water-based muds (SWBM) has been mixed: they are extremely effective in inhibiting swelling and dispersion of claystone and chalk, however some concerns exist over the stability of the system in terms of fluid properties, long term wellbore stabilisation and lubricity. This paper details new results, previously unreported, which give a better insight into the mechanism of clay stabilisation using SWBM.
Recent literature has suggested that silicate fluids are as effective as oil-based muds (OBM) in wellbore stabilisation.
This paper describes research and development indicating that silicate precipitation occurs within shales to form a barrier or membrane that hinders ion movement. However, there are distinct differences between the efficiency of membranes produced by oil based and silicate water based muds. Results are included which demonstrate that the ion- exclusion membrane is not as effective with Silicate systems as it is in OBM. New core flow experiments demonstrate that a permeability reduction with silicates and a slow rate of ionic equilibration are the principal causes for the osmotic barrier seen in swelling tests.
Further results indicate a change in the physicochemical nature of clays after exposure to high pH silicate fluids. It appears that redistribution of alumino-silicate occurs which may play an important role in the inhibitive nature of these fluids.
These evaluations are placed in context with well data in which primary considerations are the nature of any lost time incidents and overall SWBM performance.
P. 897
Whipstock Performance Review in Gulf Coast Region Yields Operational
Authors: Hinojosa Robert , Ryan Jimmy , Wyman Richard , Wiley Barton 
Published: December 2007

Abstract
When sidetracking a wellbore the decision must be made whether to cut a section or mill a window in the casing. There are specific instances when setting a whipstock and milling a window is the better option. The performance of whipstocks is dependent both on certain well parameters and post milling operations. The parameters such as depth, hole angle, cement status, casing size, weight and grade, and distance to be drilled to a large degree are fixed. Post milling operations seem to present the best avenue to ensure good window performance.
Investigation on Formation Damage Control of the Methylglucoside Fluids
Authors: Zhang Yan , Chen Zhu , Yan Jienian 
Published: December 2007

Abstract
The invasion of mud filtrate with associate fine particles may impair rock permeability around the wellbore. The control of formation damage induced by drilling muds has long been recognized as part of good drilling practice. Utilizing the muds with improved filtration control characteristics provides an efficient method of limiting the extent of damage. It is highly desirable for drilling muds to form an impermeable mud cake quickly, thereby reducing the spurt loss and cake thickness. The Methylglucoside fluid, designated as the MEG fluid, is a recently developed environmentally acceptable water-based mud and its performance approaches the oil-based muds. Previous investigations have shown that the MEG fluid is very shale stabilizing, and has superior lubrication and filtration control properties.
This paper presents the experimental procedures, results and analysis performed on formation damage characteristics of the MEG fluid. Core flow tests were conducted using the MEG fluid and three other commonly used drilling muds. Two types of sandstone cores with high and low permeability were used in the experiments. The depth of invasion of filtrate and fine particles present in the MEG fluid were evaluated. Laboratory results have shown that the MEG fluid is superior in the formation damage control, Compared with conventional drilling muds, the extent of damage caused by filtrate retention of the MEG fluid is smaller and the return permeability is higher. Also, the MEG fluid has an excellent property of filtration control.
To investigate the mechanism of why the MEG fluid controls formation damage, a series of experiments were conducted which include the cake texture observation, the particle size distribution analysis, inhibition evalution and the measurements of surface and interfacial tension etc.
P. 241
Water Base Drilling Fluid Replaces Oil Base Mud to Control Formation Damage
Authors: Ray Ananda Kumar , Singh Lehmbar , Dinesh R. S. , Singh Daljit 
Published: December 2007

Abstract
Alpha field is a sand stone, mixed drive reservoir, located in Cambay Basin of India. The exploitation of the reservoir continued since 1969 resulting in decline in reservoir pressure which in turn made drilling of infill wells, avoiding formation damage difficult. The reservoir was to be put on polymer flooding for which 16 infill wells were to be drilled. A few infill wells drilled in past had shown high formation damage. High mud weight was found to be the root cause. Therefore oil base mud was experimented in one well resulting in no formation damage but at high cost. On economic consideration it was thought to try low gravity water base drilling fluid in one well with a change in the prevailing casing policy. The strategy worked and the well so drilled and completed resulted in no formation damage. The same strategy was followed in remaining infill wells and all of them were successfully drilled. The field trial thus demonstrated how application of low gravity water base drilling fluid with judicious casing policy can control formation damage and may be better alternative to costly non-conventional method like oil base mud.
Physics and Modeling of Permeability Damage Induced by Particle Deposition
Authors: Chauveteau G. , Nabzar L. , Coste J-P. 
Published: December 2007

Abstract
The different mechanisms leading to permeability damages due to particle deposition are analyzed under various situations relevant for oil production. The analysis is based on the relative importance of the forces involved in the various deposition processes. In this way, different deposition regimes, characterized by the values of a few non-dimensional numbers, are defined. Among the major parameters, some are conventional and usually considered, such as particle and pore sizes, flow rate, particle concentration and suspending fluid viscosity. However, other parameters, which are often ignored, such as particle and pore shape and roughness, particle-particle and particle-pore wall interaction energies as well as pore surface physicochemical heterogeneity play an even more important role. In all cases, the regime determines deposition kinetics and the location where particles are deposited inside porous structure. As a consequence, determining both the deposition regime and the mechanism of permeability damage involved are prerequisites before any attempt to model and to predict permeability reduction. Due to the complexity of practical cases, experiments must be carried out to define the regime and the values of the major parameters used as input in a suitable formation damage model. Comparisons between model predictions and experimental results obtained under well-controlled conditions show the cases where presently the permeability damage modeling is reliable.
P. 409
New Acidizing Techniques Prove Useful in the Offshore Environment
Authors: Harvey R. , Smith C.J. , Wylie M.P. , Eberhard J.E. , Chapman B.J. , Vitthal S. , Gidley J.L. 
Published: December 2007

Abstract
Acidizing oil wells in sandstone formations often causes a variety of problems, ranging from inadequate productivity response, and unwanted stimulation of water, to the upsetting of surface separation facilities. A simple, economical, and effective change in the procedure for conducting these treatments involves displacing the oil from the zone to be acidized with a miscible gas, preferably CO2. Such displacement, often called preconditioning the formation, prevents interaction between the acid, its reaction products, and the resident oil. Field results with this treatment indicate an improved productivity response, less stimulation of water, and reduced emulsion separation problems at the surface.
Previously published information on this process was taken from a single field offshore Louisiana and involved the use of conventional mud acid (HF/HCl)1. The results in this paper demonstrate that the use of CO2 has wide applicability to offshore fields and works satisfactorily not only with conventional mud acids but with a variety of organic acids as well, is to inject into the formation a preflush, normally hydrochloric acid, to displace connate water and to remove the carbonates. In some cases, organic acids (either formic or acetic) are employed instead of HCl to avoid problems with the mineralogy of the formation. The second step involves injecting an HF-containing acid to react with clays, feldspars, and other materials thought to be the source of damage. The mixture most often employed is one of HCl and HF, although organic acids are sometimes substituted for HCl because of the sensitivity of certain formations to HCl.
P. 515
Aluminum Scaling and Formation Damage due to Regular Mud Acid Treatment
Authors: Nasr-El-Din H.A. , Hopkins J.A. , Shuchart C.E. , Wilkinson T. 
Published: December 2007

Abstract
Accurate formation damage identification significantly improves the success of a remedial stimulation treatment. In an oil-producing well in Central Saudi Arabia, the electrical submersible pump (ESP) used to lift the oil from the well was damaged and needed to be replaced. Production engineers observed a deposit on the impeller of the pump. The deposit was also suspected of plugging the formation and significantly reducing oil production.
Laboratory analyses of the scale deposit by XRD, XRF, and SEM revealed an amorphous material containing a high concentration of aluminum. After extensive examination, it was determined that the only possible source of aluminum was a previous HF stimulation. Examination of the well history showed that a typical 12% HCl-3% HF mud acid stimulation treatment was conducted during the original drilling and testing of the well. 9F NMR spectroscopy indicated that the deposit contained F/Al molar ratio of 0.4, consistent with precipitation from completely spent HF fluids. Solubility showed that 70 to 85 wt% of the deposit could be dissolved with 15 wt% HCl, if it could be contacted.
A retarded HF acid based on aluminum chloride was designed to remove the deposit and improve well productivity. A wellbore clean-out with 10 wt% HCl was conducted to remove very near wellbore deposits. In addition, a large HCl preflush, twice the volume of the HF stage, was pumped before the retarded HF to remove deposits within the formation. All acid fluids contained 2–5 wt% acetic acid and 50 lbs/Mgal of citric acid to prevent precipitation of aluminum and iron.
Special efforts were made to recover spent acid fluids. Return fluid samples were collected throughout the flowback. Complete fluid analyses are discussed along with their implications. Considerable acid spending was observed from dissolution of the aluminum deposits and carbonate minerals. The presence of carbonates suggests precipitation of aluminum within the formation matrix.
The retarded HF treatment design successfully removed aluminum precipitation damage from the previous HF treatment. Production of the well stabilized at nearly twice the pre-stimulation levels with no further re-occurrence of the aluminum scaling problems.
P. 539
Upscaling of Reservoir Properties Using Wavelets
Authors: Jansen F.E. , Kelkar M.G. 
Published: December 2007

Abstract
The wavelet transform has the ability to preserve local structures in spatial data sets. This paper presents a technique by which wavelet transform is used to upscale the fine scale permeability values in 2 and 3 dimensions. The method is easy to implement and very efficient. Although not based on preserving the physics of the flow process, it is able to capture the flow processes in both 2 and 3 dimensions. Further, the method also compares favorably with other upscaling techniques.
P. 23
Capillary Pressure Correlation for Mixed-Wet Reservoirs
Authors: Skjaeveland S.M. , Siqveland L.M. , Kjosavik A. , Hammervold W.L. , Virnovsky G.A. 
Published: December 2007

Abstract
For water-wet reservoirs, several expressions may be used to correlate capillary pressure, or height above the free water level, with the water saturation. These correlations all feature a vertical asymptote at the residual water saturation where the capillary pressure goes to plus infinity.
We have developed a general capillary pressure correlation that covers primary drainage, imbibition, secondary drainage, and hysteresis scanning loops. The graph exhibits an asymptote at the residual saturation of water and of oil where the capillary pressure goes to plus and minus infinity, respectively. The shape of the correlation is simple yet flexible as a sum of two terms, each with two adjustable parameters and is verified by laboratory experiments and well-log data. An associated hysteresis scheme is also verified by experimental data.
The correlation can be used to make representative capillary pressure curves for numerical simulation of reservoirs with varying wettability and to model and interpret flooding processes.
P. 39
Depositional Model of the L-III Horizon in a Sector of Bombay High South Field and Its
Authors: Sharma P.K. , Abdurahman Kutty , Rautela P.S. , Shrivastava R.K. 
Published: December 2007

Abstract
The Lower Miocene L-III limestone reservoir of Bombay High South, Western offshore, India, is a multi-layered reservoir. It has been divided conventionally from top to bottom into major layers A, B, C, D, E, and F separated by intervening shale and argillaceous tight limestone. A' layer is further subdivided into Al, A2-I, A2-lI, A2-III, A2-lV, A2-V, A2-VI and A2-VII and along with layer B constitutes the main producing horizon. Identification and mapping of individual layers and facies distribution in them has important implications in the effective reservoir management as well as performance prediction. The present paper attempts to work out a depositional model for these layers through integration of log, core and reservoir data in order to explain the spatial and temporal variations in the distribution of poro-perm characteristics of flow units.
Based on log characters and core data, a tidal depositional model has been evolved. It has been envisaged that the carbonate layers have been deposited in a tidal regime comprising supratidal, intertidal and subtidal environments. Though the deposition has taken place in shallow lagoonal conditions, the reworking effect of the tidal waves in a regressive regime has given rise to the carbonate deposits in the tidal channels and adjacent levees, and shale in the marshes. These layers have also witnessed subaerial exposure. Starting from C and B layers, during their deposition, the environmental conditions were uniform without much facies and thickness variation and the area had an open marine influence as indicated by the presence of pelecypod shells and other associated fauna. These layers, along with the overlying N shale, have been designated as Sequence I. The overlying A2 -VII and A2-VI layers, deposited in a subtidal regime are termed as Sequence 2. The layers A2-V and A2-IV represent an intertidal regime and constitute the Sequence 3. Finally, the carbonate cycle ends with intertidal environment having influence of supratidal regime comprising the layers A2-IIl, A2-lI, A2-I and Al. The occurrence of microdolomite/ dolomitic wackestone in this sequence supports the presence of supratidal environments. The sequences are identifiable on GR log showing diagnostic log features.
In general the area has been under the influence of a regressive cycle during the deposition of sequences 1 to 4. At micro level, however, each stratigraphic sequence has witnessed deposition of different facies due to fluctuations in bathymetry. In the ultimate analysis, the model will provide significant leads about reservoir facies changes in time and space and help in recognizing the horizontal and vertical poroperm variations in the different flow units of the prolifically producing L-III horizon.
P. 677