bluuebunny/crossref_metadata_2025_split huggingface dataset:
Using Mudlogging Data to Prevent Drilling Problem when Approaching Granite Basement of Cuulong Basin
Authors: Han Dinh , Nguyen Phung , Le Chung , Nguyen K.H. , Nguyen L.H. , Chu P.T. 
Published: February 2011

Abstract
The paper is the case study of catching basement in specific Basin of CuuLong which is considered as major production field of Vietnam. The case study is conducted on experience of Mud-logging service and Well Site Geologist (WSG) service of PVDLogging, which is subsidiary of PVD Company.
Production of the basin is mainly found in fractures of Granite basement. Those fractures could cause the major loss of drilling fluid when hitting the top of basement (TOB). The accuracy in identification of this top while drilling is one of the key successes of drilling operations.
Methodology is combination of drilling parameters behavior accordingly to the bit type when approaching the top of granite with or without confirmation of lag data and mud-logging data, such as formation gas, lithology and variation in mud pit volumes. The appropriate application of this method is able to catch the TOB in this field earlier than using Logging While Drilling (LWD) data which usually come later due to the nature design of Bottom Hole Assembly (BHA).
Openhole Stability and Solids Production Simulation of Emerging Gas Shales Using Anisotropic Thick Wall Cylinders
Authors: Hoang Son K. , Abousleiman Younane N. 
Published: February 2011

Abstract
Although unconventional gas shales have become accepted as the game changer for natural gas (International Energy Agency’s 2009 World Energy Outlook), laboratory as well as simulated data of openhole completion and production accounting for the inherent anisotropy and low permeability of gas shales are still extremely limited, due to the great challenges in testing and modeling of shale under in-situ openhole conditions. First, shale frequently exhibits substantial mechanical anisotropy that affects the stress distribution around an open hole. Second, the intrinsic low permeability of shale, sometimes on the order of nano-Darcies, magnifies the effects of time-dependent pore pressure on the effective stresses and could cause complex rock failure behavior. In this study, the response of anisotropic thick wall cylinder shale samples under realistic laboratory time-dependent loading, simulating near-wellbore or near-perforation production stresses, is modeled and analyzed taking into account fully coupled fluid and shale matrix interaction to address these challenging issues. Extensive experimental results including thick wall cylinder tests on an anisotropic low-permeability shale were analyzed using the developed analytical simulator. The analysis showed that depending on shale permeability and loading rate, solids production could result from either shear collapse mechanism or a combination of shear and tensile failure of the rock matrix. Thick wall cylinder tests on Woodford Shale and Barnett Shale were also simulated using experimentally measured mechanical and petrophysical properties. The results showed that the stress required to initiate solids production significantly depends on the loading rate as well as sample size, and is considerably higher than predicted by conventional elasticity theory. The presented modeling will be essential for designing and interpreting thick wall cylinder tests on gas shales as well as the ensuing modeling of gas production from these formations. The results on Woodford Shale and Barnett Shale will serve as guidelines for field operations and future laboratory testing.
CO2 Sequestration Wells - The Lifetime Integrity Challenge
Authors: Smith L , Billingham M A , Lee C-H , Milanovic D. , Lunt G. 
Published: February 2011

Abstract
The technical challenges of CO2 injection wells are highly dependent on the individual well design parameters, principally the formation being injected into (saline aquifer versus depleted gas formation) and the quality (impurity levels) found in the CO2 source gas. These factors will impact the potential corrosion and other material degradation challenges which may threaten the well components including injection tubing, injection casing, cement and packer materials. The long term integrity of these components is critical to the injection phase of the life and the suspension and abandonment phases (depending upon the strategy selected for well abandonment).
A key part of the acceptance of CO2 sequestration as a safe and reliable greenhouse gas control mechanism will be the proof that the well is truly leak-free. This integrity management element requires a comprehensive monitoring and pro-active warning system which highlights developing integrity issues before they become acute. Key well parameters requiring daily monitoring and intermittent testing have to be identified developed from industry international standards and regulations. Continuous well condition monitoring will require a dedicated well integrity software system which can integrate all relevant data from multiple sources. Data must be continuously automatically analysed using the software with developing well integrity problems identified and alerted to the operators before conditions become critical. Such a software has been recently deployed in gas storage wells and can be customized to CO2 sequestration wells.
Engineering a Successful Fracture-Stimulation Treatment in the Eagle Ford Shale
Authors: Stegent N. A. , Wagner A. L. , Mullen J. , Borstmayer R. E. 
Published: February 2011

Abstract
The Eagle Ford shale in south Texas is the one of the most recent developments in unconventional reservoir exploration. Numerous existing completion methods have been applied in this nano-darcy formation with various degrees of success. The horizontal Eagle Ford wells in the northeast area of the current Eagle Ford play (DeWitt County) require a completion strategy that is reservoir specific. The production in this area has a high liquid/gas ratio and presents different challenges for commercial development than those in the typical “high-rate water frac” completions associated with dry-gas shale stimulation theory. Previous high-rate water frac completions in this area typically associated with the “Barnett-style shale stimulation” achieved poor results. Core analysis shows that a low Young's Modulus (YM) (soft rock), high clay content, and the potential for high liquid-hydrocarbon production require the need for a different completion strategy. Swelling formation clays and proppant embedment were formation issues to consider along with the multiphase hydrocarbon production. Higher conductivity fractures would be required, but various unknowns existed: How many frac stages should be pumped?How much proppant should be pumped on each frac stage?What type of proppant should be used?What mesh proppant should be used?What perforation scheme was needed?What type of completion fluids should be used?What injection rate was needed?How would fracture-injection issues be handled?
This paper discusses how a collaborative, engineered approach was applied to the completion of the Eagle Ford shale to deliver a commercial asset. To address the unknowns, the methodology included geologic and reservoir understanding applied to the stimulation design and execution. The stimulation resulted in hydrocarbon production that exceeded expectations. Comparative well results will be discussed.
Technically and Economically Improved Cementing System with Sustainable Components
Authors: Brandl A. , Bray W.S. , Doherty D.R. 
Published: February 2011

Abstract
The benefits of cementing systems containing high percentages of pozzolanic materials (abbr. “pozzolan” systems) were investigated and compared to conventional API cement systems at same densities. Besides the presentation of technical results based on laboratory tests, economical and ecological features were also considered. For the tested pozzolan systems up to 65% of the cement was substituted with sustainable minerals, resulting in a significantly reduced CO2 footprint and costs. Slurry performances (rheology, stability, and fluid loss control) as well as properties of the set systems (water permeability, compressive and tensile strength) were evaluated for various densities and temperatures. The results reveal that the pozzolan systems generally require lower additive dosages to adjust the desired slurry performances. Furthermore, strength and durability (towards retrogression and corrosion) are consistently more favorable for the pozzolan systems. Findings were related to the working mechanisms of the used pozzolans in cement systems. The study proves that improved technical performance, economics, and sustainability can be combined together in appropriately designed pozzolan systems.
Application Mapping Methods in Well Intervention Planning
Authors: Volkov V. G. , Volkov M. G. , Elichev V. A. , Topolnikov A. S. 
Published: February 2011

Abstract
The paper proposes a system approach to well intervention planning based on application area mapping. A sorted set of graphs, schemes and maps reflecting underlying analytical models is used as the input material for a workflow-controlled express analysis of the technological decisions made that will help in forecasting future intervention operations.
The most problem is that we have a lot of different information. The main idea is to combine and filtering the information and build easy to analysis pictures using various visual representation techniques. So fast reservoir development analysis becomes possible and we can use it to support real-time and "quasi" real-time operations.
The graphical analysis workflow is subdivided into the following stages: importing the input data; processing the input data (applying the required criteria, templates and models); output of the resulting information; and generating the final conclusions. This method is considered efficient in intervention program designs, as long as it: allows of simultaneous processing of data obtained from different sources; is founded on time-proved models and algorithms; makes use of various visual representation techniques (trend lines, threshold levels, applicability boundaries, threshold efficiency and economic practicability); and dramatically reduces the analysis time.
Those methods have been successfully applied during the development planning of the oil fields in Russian West Siberia. It is planning to automate those methods and use those for Decision Support Centers.
Real Time Data Management and Information Transfer as an Effective Drilling Technique
Authors: Vogel Steve , Asker Jamal 
Published: February 2011

Abstract

Description
This paper is presented to enlighten operators and other drilling organizations in the cost-effectiveness and importance of real time data management techniques and information transfer complimenting technology in drilling operations at certain scenarios.

Applications
The techniques in this paper will increase the awareness of real time drilling efficiency and cut drilling cost. The techniques included are; continuous monitoring of real-time drilling parameters for quality and consistency, a seamless mechanism to correct inconsistencies in the data delivery, effective informational transfer and solutions delivery. Unique applications to analyze drilling with mechanical specific energy (MSE) in real-time and not just MSE, but an efficient MSE, which takes into consideration BHA specifications and theoretical down hole parameters, the use of reference channels, which is data that has been obtained from a previous offset well and training the rig crew in drilling awareness and the understanding of drilling mechanics.

Results, Observations and Conclusions
The results of this execution include quality real time data delivery, increased operational awareness, streamlined decision making, improve drilling efficiency and lower drilling costs. The observations reveal that a review of historic versus actual real time data delivery, field case study results and methodologies enacted demonstrate the effectiveness of the use of this implementation and the value to the user. The conclusions made are that quality data will allow a sufficient real time drilling monitoring system which provides effective improvements in the drilling operations results.

Significance of subject matter:
Demonstrating the importance of quality real time data for drilling optimization practices.
Present methodology and characteristics for system employed.
Provide vehicle for additional cost savings to the E&P industry.
Benefit Knowledge Transfer process by reducing inconsistencies.
Successful Testing of Toe-To-Heel Waterflooding in Medicine Hat Glauconitic C Reservoir
Authors: Turta A. , Singhal A. , Hawkins B. , Fisher D. 
Published: February 2011

Abstract
The Medicine Hat Glauconitic C reservoir contains medium heavy oil, and was put on production in 1985. In 1993, a waterflood pilot was initiated; in 1996, several horizontal wells were drilled as producers, and they resulted in a spectacular increase in oil production. In 2001 a conventional field-wide waterflood was implemented. The waterflood included seven Toe-To-Heel Waterflooding (TTHW) modules involving 10 injectors and 18 horizontal producers, out of a total of 52 injectors and 100 producers.
Five of these modules that utilized vertical wells as injectors performed well; oil rate increased 2 to 11 times, as increases in oil production continued for several years, or stabilized. During the same period, the performance of conventional waterflood modules was characterized by reductions in decline of oil production trends. Two TTHW modules that used horizontal injectors performed similar to conventional waterflood modules.
The best performance was shown by Module # 5 (involving two horizontal producers and two vertical injectors), located in the best quality reservoir. Compared to conventional waterflood pilot area nearby, the performance of Module #5 was superior, with oil production rates increasing 7-11-folds, while in the pilot area this was only 2-3 times; the water injected/oil produced ratio was 12–15 m3/m3 for Module #5, while it was 24–44 m3/m3 for the pilot area. The incremental oil recovery due to waterflooding from the TTH module # 5 was estimated at about 7%, and 5% from a nearby conventional waterflood area.
A statistical analysis for the whole field revealed that TTH horizontal wells produced at oil rates 30% higher than the non-TTH configuration horizontal producers.
Measurement of Recovered Solvent in Solvent Aided Process
Authors: Gupta S. , Gittins S. 
Published: February 2011

Abstract
Solvent Aided Process (SAP) is a solvent based enhancement of SAGD where small amounts of solvent such as light alkanes or natural gas liquids are added to the injected steam to enhance reservoir performance and associated project economics. Expectedly, the economics with SAP are sensitive to the solvent recovered from the reservoir, making its measurement in a field test an important factor.
When a single-component solvent like butane, which is not generally present in the produced heavy oil or bitumen, is used in SAP, estimation of the recovered solvent can be achieved uniquely. But when the solvent also has heavier components, some of which overlap with the lighter components of the produced oil, the measurement is not straightforward. The problem is compounded by the fact that the interaction with reservoir changes composition of the produced solvent and makes it time-varying on account of different resident times associated with different components. The issue is further complicated by the fact that produced oil also undergoes an in situ solvent de-asphalting process (SDA), which is also time and space varying in the reservoir. If there were no in situ SDA, one potential method to measure the amount of produced solvent would be to measure the total asphaltene content as an oil ‘marker’ in the produced blend. Use of a tracer with injected solvent as well as regression based analyses for solvent-fraction (using compositional analyses of solvent, bitumen and the blend) of the produced blend is error-prone for these same reasons.
Due to the issues in the approaches mentioned above, a new method is desirable for a more robust and unique assessment of the solvent amount in the produced fluids. This paper elaborates on the current challenges and proposes a couple of workable methods including use of maltenes-metals content as oil markers as well as the use of boiling point curves of the produced blend compared to that of the base oil.
Such techniques of estimating the recovered solvent can facilitate a more objective assessment of SAP field tests and enable economic evaluation of its application to a commercial scale.
Partial Upgrading of Bitumen at SAGD Wellsite
Authors: Fukuyama H. , Nakamura T. , Ikeda A. 
Published: February 2011

ABSTRACT
The high-conversion soaker cracking (HSC) process, an advanced continuous thermal cracking, has been used commercially for more than 20 years at a refinery converting heavy oil to valuable lighter distillates. The residue from the process is the heaviest liquid fuel in the world and is used for a boiler at the refinery. The application of HSC was studied as a partial upgrader at a SAGD wellsite to improve the transportability of bitumen using thermal cracking for the reduction of diluent volume and replacement of natural gas with the cracked residue from the HSC process for steam generation at the boiler. The advantage of HSC was examined by conducting thermal cracking tests using Athabasca bitumen. Material balances of the integrated SAGD and HSC for different SORs were calculated to obtain blended oils with API 21 for pipeline transportation. The calculated values were compared with the material balance of the standalone SAGD, based on the results of the test. The economic study of SAGD/HSC integrated process compared with the standalone SAGD showed that the IRR of the integrated SAGD/HSC was less volatile to the WTI and the natural gas market price. The economic benefit of partial upgrading of bitumen at the wellsite was more pronounced for higher prices of WTI and natural gas.
Advantages of Managed Pressure Drilling and the Recent Deployment of the Technology in Vietnam
Authors: Nas Steve , Gedge Ben , Palao Felbert , Viet Bot Nguyen 
Published: February 2011

Abstract
Managed Pressure Drilling (MPD) is a technology that accurately controls the annular pressure while drilling and completing wells. The intention of MPD is to avoid continuous influx of formation fluids to the surface. Any influx incidental to the operation will be controlled and circulated out and an overbalanced condition will be restored.
MPD can be used to reduce well construction times, which in today’s high cost rig market is appealing to any exploration, appraisal or field development team. The MPD technology can, to a certain degree reduce drilling fluid related formation impairment, and can through the reduction of the mud weight reduce the cost of mud losses as well as the related non productive time that is spend in curing losses.
MPD technology is now deployed extensively in the Asia-Pacific Region by many operators, to alleviate a range of pressure related drilling problems. The main applications for MPD include pressurized mud cap to deal with the kick/loss situations in fractured carbonates as well as constant bottom hole pressure systems in wells with narrow pore pressure fracture pressure windows or in depleted reservoirs.
This paper is intended to enhance the understanding of the value delivered through the use of MPD techniques, together with recommended equipment designs for each application. Some case studies will be used to quantify value delivery for a range of equipment designs and to better define the operational issues associated with MPD operations.
Wireline Well Tractor Technology Experience in Extended Reach Horizontal Well
Authors: Shawly Alaa S. , Buali Muhammad H. , Omran Mohammed R. , Dashash Alaa A. , Guraini Walid K. , Nawawi Ahmad A. , Al-Khamees Haider , Awami Nassar Al , Torne Juan 
Published: February 2011

Abstract
Horizontal wells with extended reach drilled in Ghawar field awarded significant improvements, maximizing hydrocarbon production and attained ultimate recoveries. Over the life of those wells, intervention work is necessary to maintain hydrocarbon production by conducting remedial action, such as acid stimulation or water shut off. Necessary data for decision making can be obtained through running surveillance tools, which has proved to be a challenge, considering that these sensors will have to be deployed to total depth (TD). Many well intervention methods have been developed over time to overcome these challenges, such as coiled tubing (CT) and several types of wireline tractors.
Wireline tractor technology has evolved to reduce time, cost and improve data quality and increase wellbore coverage. The use of a wireline tractor imposes fewer personnel on the job, much less equipment and less lifting of heavy loads resulting in a smaller footprint impacting the environment. In addition, the fast rig up of the wireline tractor and the running in hole (RIH) and pulling out of hole (POOH) speeds the highly deviated section, and cuts down on operating time.
This paper will demonstrate horizontal logging experience gained from trial testing a new deployment solution for the production logging tool (PLT). A new generation of wireline tractors was utilized successfully to deploy the PLT for the first time in the Saudi Arabian field and showed exceptional performance. The tractor proved its capability to overcome different challenging wellbore conditions, such as rugosity, washouts, and high dogleg severity (DLS). Moreover, the tractor was able to efficiently pass through very short sections with large changes in the inclination and azimuth,
This paper also covers the whole cycle of candidate selection, job design, execution challenges, post job evaluation, lessons learned and experience gained to optimize similar future jobs.