bluuebunny/crossref_metadata_2025_split huggingface dataset:
Support Requirements and Innovative Solutions for a Remote Location With Difficult Cementing Challenges
Authors: Piot Bernard , Lamb Keith , Blessen Elton Al L. , Schafers Rick , Zhukin Aidar , Ferri Alain 
Published: December 2007

Abstract
This paper describes the planning and engineering of a cement slurry design in Kazakstan's remote North Buzachi field. The engineered slurry design solution required the innovative implementation of a new cementing slurry technology based on engineered Particle Size Distribution (PSD) of the slurry.
The application of the PSD technology occurred from the result of an unexpected lost circulation problem during the Phase II appraisal-drilling program conducted in 2000.
The Phase II drilling program, appraising undefined areas of the Field, experienced unanticipated fluid losses. This problem combined with gas influx problems from abnormally pressured sands, well design requirements, and the shallow depth of the wells resulted in a difficult cementing challenge.
A real time solution to the cementing program was required. The service company's area client support laboratory engineered several new slurries that were designed to provide zonal isolation, circulate a full column of cement to the surface, and maintaining well control of the pressured gas sands. The window between loss of primary well control and losing circulation was 50 psi. This extremely tight pressure window, and the speed the wells were being drilled, demanded cement slurry that could be adjusted at the last moment. A flexible cement program was designed that:
Improved mud removal Incorporated pre-blended low-density slurry Enable field personnel to select cement slurry weight without having to last minute test the specific slurry weight, while maintaining optimum slurry properties. Meet all of the well design criteria
The PSD slurry design was used on the last four wells of the drilling program. The slurry density varied from 1460 to 1580 kg/m3 (12.2 ppg to 13.0 ppg). The results from these four wells were among the best obtained in the campaign, as determined by the cement bond logs (USIT & CBL), production testing, and the ability to circulate cement to surface. The review also reduced the occurrence of post cementing annulus pressure at the surface.
The program's post well review concluded that cementing design and operations based on optimum particle size distribution is effective in designing and engineering a slurry that allows last-minute weight variances while maintaining optimum slurry property performance.
This demonstrates that innovative solutions for drilling problems can be developed offsite, concurrently with the drilling operations, for implementation in remote areas having no local support.
A New Method of Evaluating the Filter-Cake Removal Efficiency
Authors: Miranda C. R. , Leite J. C. , Lopes R. T. , Oliveira L. F. 
Published: December 2007

Abstract
The removal of the filter-cake formed during the drilling operation is essential for a successful cementing job. Nowadays the use of synthetic base fluids brings the necessity of proceeding new evaluations of the efficiency of the washes in removing the filter-cake and to guarantee the wettability inversion of the formation from oil to waterwet.
It is presented here a new method of evaluating the filter-cake removal efficiency performed by different washes. This method uses a natural core with a perforation, where a filter-cake is formed by circulating a drilling fluid. The wash is circulated through this perforation and the filter-cake removal efficiency is measured precisely by Computer Tomography Scanning.
This method enables the filter-cake removal visualization during the wash circulation through the formation. From the data obtained from the X-Ray Tomography it is possible to select the most appropriate wash for a given drilling fluid, as well as to predict the necessary contact time between the wash and the formation to achieve an appropriate filter-cake removal.
World's First Benchmarking of Drilling Mud Hammer Performance at Depth Conditions
Authors: Tibbitts Gordon A. , Long Roy C. , Miller Brian E. , Arnis Judzis , Black Alan D. 
Published: December 2007

Abstract
Operators continue to look for ways to improve hard rock drilling performance through emerging technologies. A consortium of Department of Energy, operator and industry participants put together an effort to test and optimize mud driven fluid hammers as one emerging technology that has shown promise to increase penetration rates in hard rock. The thrust of this program has been to test and record the performance of fluid hammers in full scale test conditions including, hard formations at simulated depth, high density / high solids drilling muds, and realistic fluid power levels. This paper details the testing and results of testing two 7 ¾" diameter mud hammers with 8 ½" hammer bits. A Novatek MHN5 and an SDS Digger FH185 mud hammer were tested with several bit types, with performance being compared to a conventional (IADC Code 537) tricone bit. These tools functionally operated in all of the simulated downhole environments. The performance was in the range of the baseline ticone or better at lower borehole pressures, but at higher borehole pressures the performance was in the lower range or below that of the baseline tricone bit. A new drilling mode was observed, while operating the MHN5 mud hammer. This mode was noticed as the weight on bit (WOB) was in transition from low to high applied load. During this new "transition drilling mode", performance was substantially improved and in some cases outperformed the tricone bit. Improvements were noted for the SDS tool while drilling with a more aggressive bit design. Future work includes the optimization of these or the next generation tools for operating in higher density and higher borehole pressure conditions and improving bit design and technology based on the knowledge gained from this test program.
Case Studies of Casing Deformation due to Active Stresses in the Andes Cordillera, Colombia
Authors: Markley Marvin E. , Last Nigel , Mendoza Sandra , Mujica Santiago 
Published: December 2007

Abstract
Ultrasonic logging has been used extensively in Colombia, in the Andesfoothills, to quantitatively evaluate casing wear and deformation. Casingstrings can be lost to casing buckling, shearing and excessive wear. Activestresses applied to the casing strings from the active movement of faultscontribute to the degradation of casing integrity and strength.
These deformations are very costly and often cause the well bore to beabandoned or re-drilled. Imaging of the casing in planar view, 2D cross-sectionand in 3D perspective view are often helpful to better understand thedeformation extent, location, and possible causes.
A number of somewhat extreme examples of casing deformation due to activestress regimes are analyzed to demonstrate the circumstances that differentsize casings may be subjected to in areas of high lateral stresses. Some ofthese examples illustrate casing that appears damaged beyond repair, but isstill holding pressure and allows entry into the well. Other casing deformationis much less extreme, but reduces the casing strength very substantially.
Casing internal diameters, thicknesses, and the acoustic impedance of thematerial behind the casing are measured and interpreted. These measurements arethen visualized using 1D, 2D, and 3D displays of the data. Correlations togeologic and geophysical events are shown in 3D to illustrate and definepotential high-stress, problem areas and help in casing design for the severeenvironment.
Experimental Evaluation of Control Fluid Fallback During Off-Bottom Well Control: Effect of Deviation Angle
Authors: Flores-Avila Fernando S. , Smith John Rogers , Bourgoyne Adam T. , Bourgoyne Darryl A. 
Published: December 2007

Abstract
This study measured the liquid fallback during simulated blowout conditions. The purpose of the study was to establish a basis for developing a procedure for controlling blowouts that relies on the accumulation of liquid kill fluid injected while the well continues to flow. The results from experiments performed with air and water in an experimental 48 ft flow loop at 0°, 20°, 40°, 60° and 75° deviation angles from the vertical are presented. The results show that the critical velocity that prevents control fluid accumulation can be predicted by Turner's model of terminal velocity based on the liquid droplet theory by also considering the flow regime of the continuous phase when evaluating the drag coefficient, as well as the angle of deviation from the vertical. Similarly, the amount of liquid that flows countercurrent into and accumulates in the well can be predicted based on the concept of zero net liquid flow (ZNLF) holdup.
Horizontal Well Cleaning and Evaluation Using Concentric Coiled Tubing: A 3 Well Case Study from Australia
Authors: Kuchel Mike , Clark Jason , Marques Douglas 
Published: December 2007

Abstract
Some of the horizontal wells that were drilled in the Saladin field on Thevenard Island in Western Australia have produced below expectations or have experienced sharp production declines. The reasons for this were not known, although the following were suspected to be contributing factors: Reservoir quality could vary considerably.The horizontal sections were intentionally drilled in a sinusoidal shape and the low points could become traps for sand and heavy fluids.Formation damage may have occurred in some wells that were drilled with a water based mud and a high overbalance.
A specialized well cleaning system, which consists of a specially designed jet pump run on concentric coiled tubing, was determined to be a better method than conventional coiled tubing to clean the horizontal sections and investigate the causes of the production problems. The tool can be operated in a fines removal mode or a fluid removal mode which provides a localised drawdown at every point in the wellbore. The localized drawdown allows the mud-damaged zones, gas, oil and water intervals to be identified.
The well cleaning system has been successfully used to remove sand and drilling mud damage from horizontal wells in Canada, Venezuela and California. The well cleaning tool can be configured to work with different concentric coiled tubing sizes and a 1" inside 2" concentric string was designed for the Australia project.
This paper reviews the design and mechanism of the well cleaning system and provides results on the first 3 wells that were cleaned in the Saladin field.
New Downhole Tool Can Solve Depth Control Problems in Coiled-Tubing Fracturing Operations
Authors: Connell M. L. , Howard R. G. 
Published: December 2007

Abstract
Coiled-tubing fracturing (CTF) operations are proving to be a safe, cost-effective way to stimulate wells. But, the straddle packers attached to the end of the coiled tubing must be precisely placed over the intervals to be fractured or the stimulation can be compromised. A new tool has been developed to help ensure proper placement of the packers in the wellbore. A log of the casing collars is generated and then correlated to existing well logs. Once the depth corrections are made, fracturing operations can commence.
Polymer Effect on Gas/Water Flow in Porous Media
Authors: Elmkies Ph. , Lasseux D. , Bertin H. , Pichery T. , Zaitoun A. 
Published: December 2007

Abstract
The presence of hydrosoluble polymer or gel in porous media induces a selective reduction of permeability -called Disproportionate Permeability Reduction, DPR- i. e. a reduction of relative permeability to water much larger than the relative permeability to oil. Several experimental studies have been focused on oil/water systems with different cores, polymers and wettability conditions, confirming the DPR effect. The goal of our study is to investigate polymer effect on gas/water permeability in a wide range of flow rate, reproducing near well-bore conditions in water shutoff applications.
The experimental study presented here proceeds to water and nitrogen injections into sandstone cores before and after polyacrylamide adsorption. Both low-rate Darcy regime and high-rate non-Darcy regime were investigated during gas flow, the later one being modeled using the classical Darcy-Forchheimer formalism. In the Darcy regime, the DPR effect induced by polymer adsorption is more significant when observed on gas/water systems than on oil/water systems investigated under comparable conditions during previous studies. Polymer induces both a strong reduction of the relative permeability to water while affecting very little the relative permeability to gas, and a significant increase of the irreducible water saturation. In the non-Darcy regime, taking into account water saturation and permeability modifications, we observe a reduction of inertial effects when gas is injected after polymer. Experimental data are discussed and confronted with the different hypotheses put forth to explain DPR. Both DPR effect and the reduction of inertial resistance coefficients during gas flow may have important applications in gas well treatments.
Polymer Injection Projects in Brazil: Dimensioning, Field Application and Evaluation
Authors: de Melo Maria Aparecida , da Silva Ivonete P. G. , de Godoy Geraldo M. R. , Sanmartim Agda N. 
Published: December 2007

Abstract
Polymer injection in petroleum reservoirs aiming at the enhancement of oil recovery has been used worldwide for decades. Polymers act basically increasing the injected water viscosity and reducing the porous media permeability, then improving the vertical and areal sweep efficiency.
Pilot polymer injection projects for mobility correction are currently underway in three Brazilian fields operated by Petrobras, namely Carmópolis (Sergipe state), Buracica (Bahia state) and Canto do Amaro (Rio Grande do Norte state), the first and the second in full operation and the third in its initial stage. With these projects, Petrobras has acquired know-how actuating in all process steps such as the laboratory tests, the dimensioning and programming of the field operation, the field implementation and finally the analysis and interpretation of the results.
The present article describes Petrobras experience during the several phases of field projects implementation. The laboratory data for relevant parameters are presented and discussed. These data were essential to the polymer flooding projects design and serve as input data for simulation with IMEX™, which will be useful for the economical and technical evaluation of these projects.
Effect of Scale on Capillary Pressure Curves of Carbonate Samples
Authors: Wathab Mohammad 
Published: December 2007

Abstract
Capillary pressure curves are obtained for six pairs of carbonate core samples coming from a fractured reservoir in Iraq. Each pair of core samples consists of one large core sample and one small plug (that is recovered from the large core sample). Measurements are made using the porous plate method. For such measurements, synthetic equivalent formation brine and stock tank oil are used as the displaced and the displacing fluids respectively. Three types of tests are executed successively in this work; 1) large core samples at reservoir temperature (55°C), 2) small plugs at ambient temperature (about 20°C), and 3) small plugs at reservoir temperature.
Except for one sample out of the six pairs, the comparison shows that there is an upward shifting of the capillary pressure curves of the large core samples. Moreover, the irreducible water saturations obtained for large core samples are higher than those obtained for small plugs. A greater scatter is observed in the J-function for the large core samples in comparison with the small plugs. For each pair of samples, higher irreducible water saturations are obtained for core samples having wider pore size distribution (i.e. a smaller value of pore size distribution index).
The differences in capillary pressure curves, irreducible saturations and J-function are attributed to the differences in pore size distributions and scale effect. Therefore, using small plugs to measure capillary pressure could introduce severe errors in determining the capillary pressure curve and irreducible water saturation even when reservoir fluids are used.
Smørbukk field: Impact of Small Scale Heterogeneity on Gas Cycling Performance
Authors: Thibeau Sylvain 
Published: December 2007

Abstract
This paper is aiming at quantifying the interaction of small scale, permeability heterogeneity and flow performance. The work is applied to the Smørbukk gas-condensate producing field, and more specifically to its Tilje 1.1.1 formation, where injected gas is expected to expand first.
The key assumption consists in modeling small scale heterogeneity as vertical perturbations to the current petrophysical maps. Two types of data sources are used to generate these perturbations: permeability logs and mini-permeameter data. Vertically refined full field flow models are built to incorporate explicitly these perturbations.
The impact on the flow performance was evaluated in term of front developments in the reservoir; GOR evolutions at the wells and final recoveries.
Finally, an upscaling procedure is proposed to take into account the bypass of the gas cap gas by the injected gas. Analytical estimates are provided to better understand the phenomena.
Membrane Technology for Natural Gas Processing
Authors: Ohlrogge Klaus , Wind Jan , Brinkmann Torsten 
Published: December 2007

Abstract
The paper deals with the introduction of membrane based separation processes to treat natural gas according to pipeline specifications. Polymeric membranes have been tested in the frame work of a project sponsored by the European Union (Brite EuRam III, Contract No. BRPR-CT 98-0804). The focus of the work was the dehydration of natural gas streams by means of a glassy membrane and hydrocarbon dewpointing by means of an elastomeric membrane. Engineering aspects and experimental results will be discussed as well as the potential for technical applications.
A Comparison of Results of Three Different CO2 Energized Frac Fluids: A Case History
Authors: Tulissi Michael G. , May Richard E. 
Published: December 2007

Abstract
Over the past several years shallow gas reservoirs in southern Alberta have often been fracture-treated utilizing a blanket design, with the primary objective of minimizing completion costs on these marginal wells. Strategies such as simplifying logistics to take advantage of economies of scale, and reducing fluid and gas requirements have been successful in achieving this objective.
This paper discusses a pilot project, which examined ways to enhance the economics of both the Medicine Hat and Milk River formations. The ultimate goal of the project was to improve overall economics by increasing production, rather than relying solely on reduced costs. Successful trials were to provide justification for future down spacing of the field. The impact of varying the ratio of liquid CO2 relative to base fluid in twelve wells was observed.
Initial production results have proved exciting and strongly suggest the possibility of doubling production rates in the long-term.
Drilling and Completing Deep Gas Wells in Sabalo Field, Bolivia - Lessons Learned
Authors: Cunha J. C. , Passarelli R. , Venancio J. 
Published: December 2007

Abstract
Sabalo Field is located in the south of Bolivia in the Sub-Andean Region. It is a giant gas field that just recently started its development. The wells in Sabalo field demanded careful planning not only due to the high depth of the wells, but also due to the fact that its completion should be done in order to handle massive gas production (more than 2.5 MM cubic meters per day) from multiple zones. Another factor that lead to special care during the planning phase was the experience from previous wells in the area that indicated complex drilling operations with frequent reports of stuck pipe, fishing jobs, sidetracks and gas kicks due to abnormally pressurized zones.
This paper shows details of well program, operation follow-up procedure and new technologies introduced in the area in order to improve the efficiency of the operations and reduce costs of field development.
3D Analysis and Prediction of Microseismicity in Fracturing by Coupled Geomechanical Modeling
Authors: Settari A. , Sullivan R. B. , Walters D. A. , Wawrzynek P. A. 
Published: December 2007

Abstract
Microseismic monitoring is widely used for mapping fractures but the fracture dimensions are only inferred from it. This paper presents a 3-D analysis to relate the seismic events and fracture geometry. The method is based on continuum geomechanical modeling and shows that the poroelastic as well as thermal stresses are the key to explaining the characteristic pattern of events recorded in the Cotton Valley waterfracs. The method provides a tool for relating the geometry of the fracture to the microseismic image. The analysis shows that events can occur ahead of fluid and also suggests possibility of recorded events far from the fracture.
Flow Test Validation of Direct Measurement Methods Used to Determine Surface Roughness in Pipes (OCTG)
Authors: Farshad Fred F. , Rieke H. H. , Mauldin Charlie 
Published: December 2007

Abstract
The impact of applying advance metrics technology in quantifying circular pipe surface roughness insures precise and cost effective piping designs for the chemical and petroleum industries. Flow test validation of the results from the Dektak3 ST Surface Profiler® and the Hommel Tester T 1000® was performed in order to warranty that such metrics technology could quickly and effectively substantiate the effects of surface pipe roughness on friction pressure losses, and energy characteristics.
The metrics test set consisted of nine joints of 2-7/8-inch OD, chrome 13 tubular pipe sections having varying internal diameters that consists of: (1) plastic coated (IPC 800) tube; (2) electropolished Cr13 with heavy metal removal; (3) electropolished Cr13 with moderate metal removal; (4) four electropolished Cr13 samples with low metal removal; (5) mill finished Cr13 descaled by garnet blasting; and (6) mill finished Cr13 chemically descaled tube, no electropolish. The Mechanical and Fluids Engineering Department of Southwest Research Institute (SwRI) tested the pipes for the purpose of measuring pressure drop, and thereby evaluating the friction factor created by wall surface roughness in each pipe. Each section were prepared and tested for surface roughness according to the DIN 4768 (Deutsches Institut für Normung C.V.) specification using Dektak3 ST Surface Profiler® and the Hommel Tester T 1000® at the University of Louisiana. Friction-factor test results using profiling instruments with those derived from the measured flow results using the Southwest Research Institute's flow facility validated test results as predicted by the Moody and Colebrook-White equations.