bluuebunny/crossref_metadata_2025_split huggingface dataset:
Data Visualization Challenges for Displaying Laboratory Core and Flow Data in Three-Dimensions
Authors: Siddiqui Shameem , Khamees Aon A. 
Published: December 2007

Abstract
Saudi Aramco made significant progress in the last few years in setting up immersive visualization laboratories for displaying three-dimensional data on its reservoirs, wells and their trajectories. While the 3-D reservoir models using a combination of seismic, geological, well testing and log data make the displays very impressive, the essential building blocks represented by the core data are mostly absent in these visualization efforts. Core descriptions and core photographs, although have been collected for a very long time were not easy to integrate due to their analog nature. Recently progress has been made in collecting core data in digital format through core imaging, digitizing, 360-degree core photography and CT-scanning. CT has been used in Saudi Aramco for more than 10 years to generate non-destructive images of reservoir cores. However, lack of proper three-dimensional image processing software limited its use to two-dimensional image slices only. Saudi Aramco R&D Center recently undertook a project which involved testing the performance of several three dimensional image processing packages in displaying data generated by a CT-scanner. The results were very promising. Some of the software not only displayed the static data on cores but were also able to capture the dynamic sequences from laboratory waterflooding and acidizing experiments. The 3-D visualization added a new dimension to these tests as they allowed the users to evaluate and compare the performances of various treatments before they are actually implemented in the field.
Overview and Dissemination of Case Histories Pertaining to Re-Entry Whipstocks from a Coiled Tubing Deployed Perspective
Authors: Mackenzie Gordon RJ. , Wilson Steve B. 
Published: December 2007

Abstract
This paper will focus on providing the reading audience with a general overview of the practice of utilizing a whipstock methodology with the conveyance method of coiled tubing in order to create a casing / liner window. The overview will discuss general practices, tool selection criteria and provide case history demonstration of such. The case histories demonstrated will be representative of placement of the whipstock with both electric wireline and coiled tubing with actual window milling being performed with coiled tubing and workover motors. The case histories will encompass monobore applications, through tubing re-entry environments, fluid operations and also under balanced nitrogen driven applications.
Planning and Identifying the Best Technologies for Extended Reach Wells
Authors: Gupta Adit 
Published: December 2007

Abstract
This paper on ERD wells focuses on nearly all important aspects of drilling ERD wells. Various case studies have also been taken while discussing various aspects so as to signify the practical experience of ERD wells. The latest technology for drilling ERD wells has been taken up. This paper will discuss the planning of ERD wells, the latest technology for ERD wells, the consideration of drill pipes and drilling fluid design for ERD wells, completion of ERD wells, well control and fishing and workover tools for ERD wells.
At the end, suggestions have been given so as to get better results for ERD wells.
Heavy Oil Displacement by Thermal Recovery Using Different Horizontal/Vertical Wells Configurations
Authors: Alajmi Abdullah F. , Algharaib Meshal , Gharbi Ridha 
Published: December 2007

Abstract
The use of horizontal wells in oil industry has increased rapidly during the last decade. The main reason for this upsurge is that wells provide large contact area with the reservoir and therefore enhance the well productivity or injectivity better than conventional vertical wells. The high productivity coupled with the recent advances in drilling technology for horizontal wells has made their application to be an economically viable option.
The study will investigate by numerical simulation technique the performance of horizontal injection wells with production vertical wells in thermal recovery processes. A high resolution numerical simulator (ECLIPSE) will be used during the course of this research. Extensive three-dimensional, fine-mesh simulation runs will be performed to determine the oil recovery under different operating/reservoir conditions. The purpose will be to study the functional relationship between several design parameters and the oil recovery from horizontal/vertical wells configurations during thermal flooding. These parameters will include: (1) configurations of horizontal and vertical wells, (2) flood patterns, (3) Horizontal well length, (4) Mobility ratio.
Identification of Hydrocarbon Moveability and Type from Resistivity Logs
Authors: Hamada G. M. 
Published: December 2007

Abstract
Resistivity data is normally used to evaluate water saturation using porosity values from porosity logs (neutron and density). Determination of initial oil (gas) in place is based on hydrocarbon saturation, porosity and thickness obtained from openhole logging data for a given drainage area. It is important not only to determine the initial hydrocarbon in place, but also to define the existing hydrocarbon moveability, indicating the recoverable hydrocarbon and its type.
This paper presents a new approach of hydrocarbon moveability factor (HCM). This factor is derived from shallow and deep resistivity data. The relation F = a/ϕm is correct in water saturated zones, in partially saturated zones this relation becomes invalid and it will give the apparent formation resistivity factor (Fa). Based on this idea the hydrocarbon moveability factor (HCM) has been derived. With scale goes from 0.0 to 1.0. It is found that for HCM less than 0.75, hydrocarbon is moveable and for HCM greater than 0.75, the hydrocarbon is immoveable. When HCM is less than 0.25, the moveable hydrocarbon is gas and for HCM greater than 0.25 and less than 0.75, the moveable hydrocarbon is oil. Field examples have been analyzed with the HCM factor. These field examples demonstrated the contribution of HCM in the field of hydrocarbon type identification and determination of hydrocarbon moveability from openhole resistivity logging.
A Case Study: Re-fracturing of High Temperature Deep Well in Carbonate Reservoir
Authors: Wang Yonghui , Zhang Fuxiang , Cheng Xingsheng , Peng Jianxin , Li Yongping , Li Suzhen 
Published: December 2007

Abstract
To compare the effect of different stimulation techniques on carbonate reservoir and optimize the techniques, Well T was selected as a case study to test with Mini acid fracturing, cross-linked acid fracturing and hyrraulic fracturing in the same pay zone. The study showed that the effect of cross- linked acid fracturing was better than mini gel acid fracturing, and hydraulic fracturing technique was the best comparing with the others. The new idea and methods for the carbonate reservoir stimulation was gotten from the success of the 3 tests on the well.
Well T is a key wildcat well on some reef foreshore body. The well was an openhole well which was drilled on August 11th, 2004 till the depth of 4925m in Ordovician. The target zone was 4913.52-4935.00m, and the reservoir temperature was 120 °C. show was good in the target zone when drilling, and the well flowed 28936m3/d gas and a little crude oil with 8.825MPa of tubing pressure using 6mm choke without any stimulation.
Mini -acid fracturing was conducted in this well and 102m3 of gel acid was pumped on September 23, 2004. The production of gas and oil were 44270m3/d and 8.26m3/d respectively using 5mm choke at 14.463MPa of tubing pressure after the mini-acid fracturing.
Surface cross-linked acid fracturing technique was conducted on the same target zone on October 17th, 2004. 538m3 of fluid was pumped into the formation including 230m3 of pad fluid, 230m3of cross-linked acid, 56m3 of gel acid and 22m3of flush fluid. The rate was 3.5-5.6m3/min and wellhead pressure was 58-82MPa.The well produced 19906-51485m3 gas and 19.3m3 oil per day with the tubing pressure 14.99-10.03MPa using 5mm choke after the cross-linked acid fracturing.
Hydraulic fracturing was done in the same well on November 9, 2004. A total of 473.1m3 of fluid including 47m3 of proppant was pumped into the wellbore (12.2m3 40-60 mesh and 23.3m3 20-40 meshes). The well produced 33907m3 gas and 28.69m3 oil (crude oil density 0.8575 at 20 °C, no water) per day with the tubing pressure 9.48-10.3MPa using 6mm choke after the treatment. The result was encoursging.
Application and Realization of Fuzzy Method for Selecting Wells and Formations in Fracturing in Putaohua Oilfield: Production And Operations: Diagnostics & Evaluation
Authors: Dinghong Cao , Yuwei Ni , Fei Yao , Dingwei Weng , Fu Guotai 
Published: December 2007

Abstract
As the Putaohua oilfield developing, the fracturing stimulation effect is getting worse gradually, and the low efficient wells are taking a larger and larger proportion. This paper discover the oil stimulation rules of fracturing wells through statistical analyzing 300 wells’ production data before and after fracturing in Putaohua Oilfield. Based on the rules, mathematic model deduced by fuzzy method was used to instruct selecting wells and formations of fracturing wells. The application results show that the method is effective and easy to exercise, so it could be a ground for selecting fracturing wells and formations in Putaohua Oilfield in the future.
Effective Stimulation of Horizontal Wells - A New Completion Method
Authors: Seale Rocky , Themig Dan , Athans James 
Published: December 2007

Abstract
Over the last several years there have been many developments in horizontal completions. These advancements have been designed to better stimulate the entire horizontal interval. The most notable advancement has been used in cased and cemented liner applications, where composite plugs have provided the mechanical diversion that has successfully stimulated the entire horizontal wellbore. However, the process of setting a plug on coiled tubing (CT), perforating, stimulating and then repeating the process for the required number of stages to optimize production and then running back in with CT to remove the plugs is costly and time prohibitive in many cases. In open hole applications, horizontal stimulations have relied almost solely on limited entry or bullheading in attempts to induce multiple fractures. This method has proven very inefficient and unsuccessful.
A new completion system has been developed that addresses all of the prior issues in stimulating horizontal wells. This system uses a series of mechanical open hole packers deployed on the production liner with fracturing or stimulation ports located between the packers that allow for stimulation in each desired interval. Without the requirement of cementing the liner in place, all the problems associated with cementing are eliminated. By placing a liner in the open hole section rather than leaving it barefoot, accessability and production issues are more easily addressed. Additionally, the mechanical packers provide mechanical diversion at high differential pressures. The system has also been designed, so all of the fracturing or stimulation treatments along the horizontal wellbore can be pumped in one continuous operation, thus minimizing all the associated risks and optimizing the efficiencies for both the personnel and equipment. With hundreds of jobs completed, this paper will detail the operational efficiencies and reliability of this completion system, as well as analyze the cost benefits and production increases that have been noted.
Integrating Pressure Transient Analysis in Hydraulic Fracturing
Authors: Rahim Zillur , Buhidma Ismail 
Published: December 2007

Abstract
As part of HWYH Gas Plant development, hydraulic fracturing campaign commenced in 1998 to stimulate the sandstone and carbonate formations in the Ghawar gas fields in Saudi Arabia. To date, over 200 wells have been matrix acidized, acid fractured, and proppant fractured. Whereas post-treatment performance provides a good indication of treatment success, pressure transient analysis (PTA) remains the best approach to determine the effective fracture parameters such as fracture half-length and fracture conductivity. Knowledge of these two parameters is a key element to the optimization of hydraulic fracturing process.
Behavior of Proppants Under Cyclic Stress
Authors: Stephens W. T. , Schubarth S. K. , Dickson K. R. , Snyder E. M. , Doles K. J. , Herndon D. C. 
Published: December 2007

Abstract
Size distribution of proppants is one factor that determines fracture conductivity. Sufficient closure stress can cause mechanical failure of proppants changing the size distribution and altering the bulk properties of the pack. Crush resistance is one characteristic that describes how the size distribution changes under a static load. In many cases, proppants within a fracture experience a dynamic stress state that permits proppant motion and redistribution, altering the stress concentration across the proppant pack.
This paper documents the behavior of proppant size distribution under the influence of cyclic stress. While standard sieve analysis provides a good quantitative value for crush resistance, optical measurement of the size distribution illustrates proppant failure and the alteration of size distribution under load. Advanced load frames permit monitoring and measurement of the compaction process. This paper discusses the sensitivity of the size distribution with respect to closure stress and different types of stress cycles as well as the influence of alternative size distributions and proppant materials.
The results of this paper address expanding the technical evaluation of proppants using new tools and test methods to provide a greater understanding of the evolution of the proppant size distribution. Operators will be able to select proppants based upon data measured under more practical application conditions.
Well-Control Aspects of Underbalanced Drilling Operations
Authors: Ramalho John , Davidson Ian A. 
Published: December 2007

Abstract
Underbalanced drilling is not a new technology. All wells drilled up until the introduction of the rotary drilling rig were drilled underbalanced. However, knowledge of subsurface conditions was limited, well control risks were not managed and well control incidents, when wells struck over-pressured zones, were common. The introduction of the rotary rig, resulted in mud circulation systems. As wells were drilled deeper into over-pressured formations blowout preventers (BOPs) that enabled better well control were introduced. Overbalance (conventional) drilling replaced "underbalance" cable tool drilling and became the normal practice.
In conventional drilling, the hydrostatic pressure created by the mud column provides primary well control and BOPs provide secondary well control.
Underbalance drilling has emerged in the past 15 years, and, just as there have been improvements and refinements in conventional well control equipment and procedures overtime, the same holds true for underbalanced drilling technology. In underbalanced drilling, the primary well control function of the mud column is replaced by a combination of flow and pressure control, while secondary well control functionality is provided by the BOPs. The complete UBD closed-loop flow control system comprises of the drill pipe (DP) circulating system, a UBD control device (UBD-CD), which provides the sealing mechanism around the drill string at surface, a UBD choke manifold (not the rig’s well control choke manifold), a UBD separator and flare system. In addition, non-return valves (NRVs) are installed in the bottom hole assembly (BHA) and drill string to prevent flow up the DP.
This paper provides an overview of underbalanced operations primary well control. It briefly describes the equipment and techniques used and the critical issues to consider during project planning to ensure the safety of staff, the rig, the well and to ensure that the life cycle objectives of UBD wells are addressed.
Characterization of Reservoir Parameters Using Horizontal Well Interference Test
Authors: Awotunde A. A. 
Published: December 2007

Abstract
An analytical solution to transient fluid flow caused by an active horizontal well in an anisotropic reservoir is presented. The purpose of this work is to provide a means to evaluate reservoir and well parameters from observation well pressure response influencing pressure transient created by horizontal wells in reservoirs. This paper further presents dimensionless pressure and pressure derivative suitable for use in characterizing reservoir and well parameters. This work thus presents a model capable of obtaining reservoir parameters at the same time giving a good estimate of effective active horizontal well length from observation well pressure response.
The three-dimensional flow equation is employed and a method similar to that used by the Kelvin heat source solution is used in arriving at the analytical solution. The method of images is used to generate responses across boundaries. Solutions are presented in dimensionless forms for generality and suitability for use in practical field application. Results are then compared with those from existing models.
Measuring Molecular and Thermal Diffusion Coefficients in Multicomponent Mixtures by the Beam Deflection Technique
Authors: Haugen K. B. , Firoozabadi A. 
Published: December 2007

Abstract
We have extended the working equations to determine molecular and thermal diffusion coefficients by the beam deflection technique to multicomponent mixtures. In the past, simultaneous determination of molecular and thermal diffusion coefficients have only been achieved for binaries. Our proposed approach requires transient measurements from (N - 1) laser beams of different wavelengths. The beam deflection technique shows promise of being faster and more accurate than the current techniques to determine molecular diffusion coefficients.
Numerical and Laboratory Assessment of the Oil-Recovery Mechanisms in High-Pressure Air Injection (HPAI) Process
Authors: Niz-Velásquez E. 
Published: December 2007

Abstract
High Pressure Air Injection (HPAI) as an EOR process has found application in high-pressure, light-oil reservoirs, and is particularly promising for low water injectivity reservoirs. Successful HPAI projects have been reported over the last twenty years. However, there is an ongoing discussion on the manner in which the process operates. Several works have pointed out that HPAI can be assimilated to a flue gas drive, since the thermal and associated effects of the oil oxidation would have negligible effect on the overall performance. Meanwhile, calorimetric and combustion tube tests have been used to characterize the operation of HPAI at reservoir conditions. These results are then applied in field-scale simulation models to predict the recovery scenario. Although it is clear that a combination of both gas drive and oxidation reaction effects drives the oil out of the reservoir, the contribution of each process is yet to be quantified.
This work presents a methodology involving experimental tests and reservoir simulation to build a proper simulation model for HPAI at laboratory conditions and quantify the effect of flue gas drive and oxidation reactions on the total oil recovery.
Calorimetric, PVT, flue gas floods and combustion tube tests are available for two light oils. This data is used to extract information about the recovery of each driving mechanism via reservoir simulation. Two- and three-phase (light oil/flue gas/water) displacements are conducted in a foot-long Berea Sandstone core to analyze the effect of saturation history, pressure, temperature and phase composition on the oil recovery at typical process conditions. Same oil species as in the rest of the experimental data are employed. A thermal simulation model for combustion tube tests is built based on the information from individual experiments, and refined by history matching.
Reservoir simulation of a combustion tube test by incorporating history-matched relative permeability curves shows that a flue gas drive process alone cannot explain the high recovery seen in the laboratory.
New Multifunctional Polymeric Additives for Water-Based Muds
Authors: de Almeida Rodrigues J. , Lachter E. R. , de Sá C. H. , de Mello M. , Nascimento R. S. V. 
Published: December 2007

Abstract
The present work had the purpose of developing a new class of polymeric additives for water based muds (WBM), that would present simultaneously several properties needed for a good performance, also being ecologically correct and of low cost. The additives were obtained through the chemical modification of hydrophilic polymers by coupling different hydrophobic segments to one or both end groups. The rheologic analysis of some aqueous systems of the obtained products showed a pseudoplastic behavior, and it is suggested a model to explain the obtained results. A series of drilling fluids was formulated with the best systems studied. The developed fluids successfully played the functions of rheologic modifiers, shale inhibitors, filtrate reducers and lubricants, getting excellent results in Low Pressure and Low Temperature (LPLT) conditions.
Remediation of Production Loss Due to Proppant Flowback through Coiled-Tubing Intervention
Authors: Ingram Stephen R. , Nguyen Philip D. , Hood Al 
Published: December 2007

Abstract
This presentation discusses the results of experimental and field case studies of a remedial treatment technique designed to eliminate fracture proppant production. This process uses a low-viscosity consolidating agent, which is placed into the propped fractures via coiled tubing or conventional tubing coupled with a pressure-pulsing tool. The treatment fluids are designed to provide consolidation for previously placed proppant near the wellbore without damaging the permeability of the proppant pack. The consolidation treatment transforms the loosely packed proppant in the fractures and the formation sand close to the wellbore into a cohesive, consolidated, yet highly permeable pack.
Laboratory gas flow testing indicates that the proppant pack in a fracture model under closure stress required low-strength bonds between proppant grains to withstand high production flow rates. Field case histories are also presented to discuss treatment procedures, precautions, and recommendations for implementing the treatment process. One major advantage of this new remedial treatment technique is the ability to place the treatment fluid into the propped fractures, regardless of the number of perforation intervals and their lengths, without mechanical isolation between the intervals. The fluid placement efficiency of this process makes remediation economically feasible, especially in wells with marginally economic reserves.