bluuebunny/crossref_metadata_2025_split huggingface dataset:
Integrated Fracture Study using Formation Micro Imager, Stoneley Waves and Formation Evaluation Results in Carbonate Reservoir at Gulf of Suez, Egypt
Authors: Bassim Essam A. E. A. , Yamaguchi Kaoru , Juandi Dedi , Emam Mahmoud , Ali Aziza 
Published: March 2009

Abstract
The carbonate reservoirs in Gulf of Suez area have complex geological structure due to the existence of fractures associated with faults. Thus, fracture characterization of this complicated area is very important to understand the reservoir behavior and hence assigning the best completion intervals for the producing wells.
In this paper, we developed a workflow of integrating formation micro imager, Stoneley waves and petrophysical analysis for better fracture characterization and selecting the best perforation intervals for a producing well. This workflow is applied on well NWO-1, in the Northwest October Concession in the Gulf of Suez area over the carbonate reservoir.
The well was drilled on the peak of anticlinal feature created by fault propagation fold of a normal fault that located nearby the well. The main objective was to determine the structural geology features (i.e. fractures), its orientation and the diagenetic features (i.e. vugs) using formation micro imaging tool. Also, to quantify the effectiveness of fractures as fluid conduit mainly in the carbonate reservoirs either in Thebes or Mokattam Formation via Stoneley waves derived from processing result of sonic measurement. This is combined with the petrophysical interpretation using the elemental spectral device data and other conventional open hole logs to provide a comprehensive petrophysical formation evaluation.
The study reveals that the highest average fracture density is over (Layer-A & B) at the upper most interval of Thebes Formation around 2.2 fractures/ft and (Layer-C) at the bottom around 1.77 fractures/ft. These fractures were proved to be of good fluid conduit based on both Stoneley waves and the petrophysical interpretation. The two layers A and B were recommended to be tested and the DST (Drill Steam Test) results proved the higher productivity than layer C which confirms the outcome from our integrated study.
Awareness and Expectation—Gender in the Workplace
Authors: Lau Richard , Lau Laura , Al Hasani Nadia 
Published: March 2009

Abstract
One of the most important legacies of the late President, Sheikh Zayed Al Nahyan left to the people of the UAE was his insistence that women participate fully and equally in the growth and prosperity of the UAE. This paper examines the readiness of students, professors and professionals to accept women in professional roles in the oil and gas industries in the UAE.
Working at the Petroleum Institute in Abu Dhabi, the researchers train both men and women to become future engineers for the Abu Dhabi National Oil Company (ADNOC). In this study, future and present professionals were asked to rate their opinions about working with women in integrated work places. To solicit these opinions, a survey of seven questions, with a place for comments, was distributed to various age groups in various job categories. Distributed in educational institutions and local petroleum societies, the survey asked participants to rate their willingness to hire, mentor, work with, promote, and work for a woman engineer.
This paper analyzed a seven-statement survey. Finding that although most respondents agreed that greater numbers of women would be welcomed into the workplace, the researchers noted a stubborn minority of both men and women who did so with reservations. Looking for a plausible explanation, they concluded that stereotyping might be a motivator.described ways that included mentoring, presenting women role models, demanding academic parity, engaging in professional activities, etc. to combat stereotyping to ensure a smooth transition of more women into the work place.examined roadblocks, like [1) low number of women, 2) retaining and promoting women employees and 3) understanding differences] that companies needed to be alert to for a successful diversified culture and then listed five strategies [1) women-to-women mentoring 2) empathy vs. advice 3) anger management 4) working through problems 5) healthy environment] that must be addressed if companies want to hire and, more importantly, retain women.concluded that while programs to address the needs and attitudes of future women engineers are in place or being established, programs for future men engineers are not. This might be the first place that women and men should look for parity.
Minimizing Risks, Maximizing On-Bottom Drilling Time: Turbodrilling with Impregnated Bits Improves Efficiency and Circumvents Trouble Time, Southern Oklahoma
Authors: Langille Peter , Deen Aron , Klassen Jay 
Published: March 2009

Abstract
Drilling in the Anadarko Basin in southern Oklahoma can present a number of distinctive challenges including fractured formations, conglomerates and other eccentric geologic phenomena. In this unpredictable drilling environment, it is difficult to optimize/refine the bit/tool and BHA selections, resulting in unacceptable or inconsistent drilling performance.
To maximize on-bottom time and cut costs, operator and service-company engineers conducted an in-depth analysis in an attempt to improve section economics. They selected a consistently troublesome application where inconsistencies in the use, performance and dull conditions of bits in close offsets were driving up field development costs. From this group, a specific interval was selected for analysis and the data compared with direct offset runs. In the study, engineers considered bit design/materials, turbodrill and BHA stabilization and drilling parameter optimization. Finally, turbodrill/impreg limitations were considered.
The analysis determined that turbodrilling with impregnated bits was a viable option to create savings and could effectively optimize drilling in applications where:
specific lithology/formation tops are difficult to define/predict deviation is caused by hard formations encountered at severe dip angles high probability of bit/tool damage from impact/abrasion excessive fishing/tripping issues hole stability/quality may be compromised by frequent trips roller-cone and fixed cutter bit performance is inconsistent
The new-style turbine/impreg BHA was run with outstanding results. The test interval was successfully drilled, eliminating multiple bit trips and reducing overall days. Cost savings were substantial versus a direct offset well that experienced 38 days of trouble time through the same formations. This trial run gives considerable strength to the hypothesis that impreg/turbine drilling can significantly reduce risk compared to traditional BHAs used in direct offsets. The operator plans to further explore the turbodrill/impreg BHA in the near future.
A Composite Seepage Model for Fractured Reservoir
Authors: Jinde Feng , Ruilan Luo , Linsong Cheng , Yuwen Chang , Lijun Yu 
Published: March 2009

Abstract
For fractured low-permeability sandstone reservoir, it is very difficult to use the conventional method to handle the stochastically distributed natural fractures, which do not connected with the wells, in the theoretical study of the naturally fractured reservoir. To study the seepage law of the fractured reservoir, a fractured heterogeneity composite reservoir seepage flow model is proposed by using the equivalent flowing resistance method. With this model, the effects of natural fracture parameters on productivity and formation pressure were investigated. The results indicate that the fractures within 10m to the wellbore will have great impacts on pressure distribution and productivity; and the impacts of fracture length, fracture aperture and fracture number on pressure distribution and productivity will decrease after they are greater than some certain value. The study clarified theoretically the reason that fractures improve the productivity.
Execution Success in a Platform Drilling Campaign
Authors: Burmaster Kolby , Chando Jesse M. , Vaczi Kenneth 
Published: March 2009

Abstract
This paper presents the results of a five-well extended reach drilling (ERD) sidetrack program in offshore California. The challenges of drilling the ERD sidetracks were compounded by potential drilling hazards, the limited capability of rig equipment, and extensive activities required to restart a cold stacked platform rig. Despite these challenges, the program was delivered 138 days ahead of schedule and 44% under budget.
This case history describes the key elements of the project that contributed to execution success, including:Early identification of technical challenges and solutionsPlanning processes that ensure alignment across functionsAn active goods and services quality initiative to maximize equipment reliabilityIncorporation of key learnings from other teams around the worldContinual redesign from well to well based on lessons learned during the execution phaseTechnical solutions that balance potential risk and reward
Specific cold start and ERD sidetrack practices are discussed, as well as the work processes that were effective in establishing a mindset of continuous improvement and flawless execution.

Introduction
Due to the significant cost of drilling, it is critical to apply a rigorous and disciplined approach to planning and execution. Maintaining a mindset of flawless execution facilitates improved performance by identifying optimization opportunities while balancing potential risk exposure (Newman 2005). The success of the operator's platform drilling campaign can be attributed to having the right team of people in place using proven planning and execution processes. These processes drove an understanding of the technical challenges and potential solutions early in the project, and ultimately delivered a five-well ERD sidetrack program ahead of schedule and under budget.

Field Overview
The Santa Ynez Unit (SYU) is located approximately 20 miles west of Santa Barbara, California. Operations in SYU comprise an oil and gas processing plant at Las Flores Canyon and three offshore platforms located in federal waters in the Santa Barbara Channel, as illustrated in Fig. 1. The three production platforms (Hondo, Harmony, and Heritage) range from 5 to 9 miles offshore and lie in water depths of 850, 1,200, and 1,075 ft, respectively. Each platform has a company-owned drilling package installed. All electricity for the drilling and production equipment is generated onshore and transmitted offshore through subsea power cables. The oil and gas produced offshore is transported through subsea pipelines to the Las Flores Canyon processing plant. These fields produce primarily low-gravity 12- to 20º-API sour crude from the highly fractured Monterey chert formation (Walker 2008).
Achieving Improved Performance Through Drilling Optimization and Vibration Management at a GoM Development Project
Authors: Plutt L. A. Jacobsen , Pere A. L. , Pardo N. O. , Rodiguez E. M. 
Published: March 2009

Abstract
The presented Gulf of Mexico (GoM) field presents drilling and evaluation challenges common to sub-salt deepwater plays. These include directional control, drilling efficiency, wellbore integrity and vibration management. Expandable reamers are used to drill challenging thin-bedded alternating sands and shales. This drilling configuration can result in high levels of vibration that can be detrimental to measurement while drilling and logging while drilling (MWD/LWD) tools. Worldwide estimated costs for vibration-related failures are in the order of $300 million per year.
A multidisciplinary team worked to deliver continuous improvement in drilling performance and risk management for the presented field during the last two years. This continuous improvement cycle has been based on comprehensive pre-well planning, downhole data acquisition with real-time diagnostics and thorough post-well analysis. This systematic approach provided the team with an accelerated learning curve from each well by enabling quick, informed decisions and learning from data, rather than failure patterns.
Although this cycle has been used throughout each well, it has proven particularly critical in the intermediate interval, which combined directional work and reaming while drilling using expandable reamers. In offset wells, before this drilling optimization approach was introduced, no well in this interval had been successfully drilled in one run.
State-of-the-art technology to monitor downhole environment in real time was introduced and enabled field personnel to react immediately to damaging vibrations by adjusting drilling parameters and applying best practices for improved borehole quality and drilling performance. As a result, this section was drilled in one run in the seven consecutive wells drilled, and all formation evaluation data acquisition and directional objectives were met with low hole tortuosity, facilitating casing placement.
This paper provides an overview of the challenges, drilling optimization process, lessons learned and best practices derived from advanced bottomhole assembly (BHA) modeling, and real-time vibration mitigation management.
Experimental Study of MSE of a Single PDC Cutter Under Simulated Pressurized Conditions
Authors: Rafatian Navid , Miska Stefan , Ledgerwood III L. W. , Ahmed Ramadan , Yu Mengjiao , Takach Nicholas 
Published: March 2009

Abstract
The downhole pressure environment is one of the most important factors affecting the rate of penetration. It is believed that impermeable rocks experience high differential pressures due to shear dilatancy and become stronger and thus more difficult to drill. However, recently performed atmospheric and pressurized single-cutter experiments show that contrary to this belief, even at low pressures (100–200 psig) and even with permeable rocks, significant increase in Mechanical Specific Energy (MSE) is observed compared to atmospheric tests.
The experiments were carried out in a single-cutter high-pressure testing facility refurbished with high-precision sensors and data acquisition system. In the experiments, a 13-mm PDC cutter was used to cut Carthage marble and Indiana limestone samples with depths of cut ranging from 0.025 to 0.050 in. More than 70 high precision tests were performed on these two rock types under confining pressures ranging from 0 to 1000 psig. The confining fluids were either water or mineral oil.
Unexpectedly, analysis of the MSE consistently showed that increases in the confining pressure as small as 150 psig can increase the MSE of the cutting process significantly and reduce the cutting efficiency by half. These reductions in the cutting efficiency that were even more dramatic in the permeable and saturated Indiana limestone could not be explained by the strengthening of the rock under confining pressures.
Upon analysis of the results of experiments (cutting forces, volume of cuts, visual inspections of cuttings, etc), a new theory is proposed to explain this unexpected behavior. This new theory, based on the frictional forces and the cutting mechanism under pressure, gives useful insights into the physics of cutter-rock interaction. Such insights are invaluable to the improvements of drilling practices selection (WOB, type of drilling fluid and its properties, etc) and the rates of penetration.
Real Time Production Monitoring Uncovers Potential for Recovery Optimization, Field Case Study, Western Desert, Egypt
Authors: Hanafy K. M. , Elsherif T. A. 
Published: March 2009

Abstract
With the dramatic increase in oil prices, oil operators are not only concerned about oil production, but also, they are aiming at the optimum oil production. Optimization of an oil producer is not easy as it might seem to be.
Moreover, oil price increase promoted for technology improvement, and set the unconventional techniques of the past to be conventional nowadays. This boom in technology application permitted high margin of investments to optimize wells/fields production, and gave production/reservoir engineers a good hand in obtaining better data for decision making.
The most important part of well/field production optimization is identifying candidates, and to recognize potentials we need to have efficient reservoir/production data. Because the whole process starts with formation inflow performance which determines how far we can go with this formation without having production problems such as; water conning, erosion induced by solid production, etc.
In this paper we are illustrating the various steps that we have taken to optimize a well producing from naturally fractured carbonate reservoir with active water drive, using a combination of modern technologies in combination with real time production monitoring systems, we were able to double this well production without entraining any problems, in addition capturing pressure transient data which enabled us to manipulate these success story with the rest of the wells in that field.
Roller Reamers Improve Drilling Performance in Wells Limited by Bit and Bottomhole Assembly Vibrations
Authors: Sowers Steven F. , Dupriest Fred E. , Bailey Jeffrey R. , Wang Lei 
Published: March 2009

Abstract
Stick-slip and whirl are vibrational problems that commonly limit drilling performance in hard formations and extended reach wells. The introduction of roller reamers has resulted in significant performance improvement in a number of the operator's drill teams with chronic stick-slip or whirl-induced borehole features.
Whirl is a dysfunction characterized by lateral vibration that may occur both at the bit and in the bottomhole assembly (BHA). When whirl becomes severe, lateral vibrations cause significant side forces in stabilizers. Frictional drag resulting from these side forces causes high levels of torque to be generated at stabilizers and can result in stick-slip (a condition characterized by fluctuations in the rotational speed of the BHA). The operator refers to this as "coupled stick-slip" because the condition is caused by whirl in stabilizers. When these conditions exist, the replacement of stabilizers with roller reamers significantly reduces the potential for torque-generation at the contact points. Consequently, more torque becomes available to the bit and the driller may raise weight on bit (WOB). This results in reduced levels of bit whirl and improved rate of penetration (ROP). The reduction of bit whirl and elimination of stick-slip prevent damage to bit and BHA components.
Roller reamers are also seen to serve the historical purpose of conditioning the borehole. The operator's field experience indicates that the need for conditioning is often due to whirl-induced features in the borehole. These features include spiraling and ledges. The use of roller reamers greatly reduces the prevalence and impact of whirl features.
This paper details the conditions where roller reamers provide benefits allowing improved performance. A conceptual model for coupled stick-slip is provided as well as a summary of whirl-induced borehole features which may be mitigated with roller reamers. Representative examples are provided that show drilling performance improvements using roller reamers to mitigate these conditions.
Improvements in Completing and Testing Multi-Zone Open-hole Carbonate Formations
Authors: Brooks Robert T. , Scott Philip , Scott Steven 
Published: March 2009

AbstractThis paper presents a methodology for executing multi-zone well tests in an un-cemented open-hole completion. Hydraulic isolation between zones is achieved using casing annulus packers rather than cement. Sliding sleeve port collars provide a means of selective interval testing, when used with polished bore receptacles and seal stacks to allow well control and test string spacing.The techniques described here eliminate cementing and perforating across reservoir intervals; therefore it is an improved method of testing multiple zones in fractured and low permeability carbonate reservoirs. Multiple zones can be individually tested and retested, in any order, on a single trip in the hole with drill stem test tools, representing a significant step change in well testing methodology.Performing well tests on single zone wells can be done in open-hole or cased hole. Open-hole well tests are usually preferred because they exhibit lower skin damage and improved productivity, especially in low permeability, fractured carbonate reservoirs. For multiple zone testing, cementing and selectively perforating are more common.A well test performed in an exploratory well in Qatar used the basis of this approach. Subsequent to this, well tests in China and Oklahoma, (USA), used this approach successfully. One common well test objective was to establish sufficient flow allowing the chosen reservoir to be evaluated, without the need to stimulate. Although stimulation was not entirely eliminated in this test case, a reduction in test time was achieved. The reduced number of trips in the hole also reduced HSE exposure. This last improvement was particularly important in one well as the well flow stream contained H2S. Although some operational difficulties were encountered and overcome, the system was proven technically viable, and has the potential for significantly reducing completion and testing time for a multi-zone well, as well as mitigating HSE hazards.
New Alternative to Selectively Fracture Stimulate Extended-Reach, Horizontal Wells
Authors: Surjaatmadja Jim B. , Sierra Leopoldo 
Published: March 2009

Abstract
The requirements of oil and gas producers to maximize hydrocarbon recovery in low-permeability environments have often been satisfied by drilling longer cased or openhole horizontal sections, or by maximizing reservoir contact by perforating multiple laterals or branches to the main bore. As production declines, these complex well completions have brought many challenges to well interventions and stimulations.
The number of such complex wells and the number of selective packerless fracture stimulations in long horizontal sections has increased significantly in the last few years, especially in Saudi Arabia in oil/gas producing wells, and eventually, for improving injectivity of water-injector wells. The selective and packerless fracture stimulation technology in wells completed with long, horizontal openholes or cased holes has not been possible until now, especially when coiled tubing is used. This is because the coiled tubing, when equipped with the selective fracturing tool, will not be able to reach the entire horizontal section without the use of mechanical tractors or agitators and because of the incompatibility of the tool assembly and tractor/agitator systems.
This paper presents, for the first time, the new tool designed to make tractor/agitator systems compatible with the selective fracturing tool. It presents a detailed job design and considerations used to perform the first field application of the tool in Saudi Arabia.
Mesophase Technology for Wellbore Cleanouts-Case History
Authors: Al-Ruwaily A. A. , Phillips J. E. , BenSaad Z. R. , Christian C. F. 
Published: March 2009

Abstract
This paper is a case history of two successful applications of mesophase technology for wellbore cleanouts and flow back enhancement. The first application was as a remedial treatment after the well's ESP pumped off and the second application was part of the completion process. Both wells were completed as open-hole horizontal wells, one with expandable sand screens (ESS) and the other with stand alone mesh type premium screens (SAS). Wells in this field are typically drilled with 65 pcf invert oil emulsion drill-in fluid (DIF) and can be as much as 800 psi over balance to formation pressure. The DIF is intuitively managed with respect to mud solids control, so there is no actual QA/QC on the solids management.
The ESS completion was treated remedially with coiled tubing (CT) and rotating jet blasters months after the completion. The horizontal well was accessed through a Y-tool bypass that was part of the ESP completion. The SAS completion was treated with CT and rotating jet blasters after running the screen and setting the packer; prior to running the ESP completion, due to casing size limitations for running a Y-tool bypass.