bluuebunny/crossref_metadata_2025_split huggingface dataset:
A Multifaceted Approach to Reducing Driving Incidents
Authors: Speer Jennifer G. 
Published: December 2007

Abstract
Driving is one of the most hazardous tasks carried out by workers in the Western Canadian oil and gas industry. Significant distances are driven on a daily basis and drivers face numerous hazards during all seasons of the year. BP Canada Energy Company Canda Gas Business Unit implemented a multi-faceted approach to reducing driving incidents. The approach aimed to reduce the frequency of driving incidents and the severity, both actual and potential, of those incidents that did occur. It includes attention to BP employees and our contractors.
In late 2001/early 2002, a driving incident reduction plan was put into place based on an analysis of previous year incident statistics. The incident reduction plan included a revised driver training program at the Schlumberger Driving School, implementing the Mission Possible at Work program (a partnership between the Alberta Motor Association and the RCMP) at all field and office locations, addressing driving issues with all major on-site contractors and finally developing and implementing leadership tools to promote better driving behavior.
The result of the driving incident reduction plan implemented in 2002 were monitored at the end of each quarter and a revised plan put into place for 2003 based on data trends.
Behavior of Crude Oil Spills: New Experimental Devices
Authors: Merlin F. X. , Poutchkovsky A. 
Published: December 2007

Abstract
Oil spill contingency plans need to propose the most operational response techniques, and consequently those best suited to the crude oil spilt. Experience has shown that the behavior and fate (weathering) of oil accidentally discharged to the environment depend on the environmental conditions and the initial composition of the product. But running tests involving spilling hydrocarbons in situ, obviously poses problems.
Experimental methods and simulations have been developed by the CEDRE (Documentation, Research and Experimentation Centre on Accidental Pollution of Water) in partnership with TOTAL E&P designed to study the evolution of a hydrocarbon in the environment, particularly in the open sea. The weathering of a crude in the short and medium term in the "polludrome" and in open pools has been studied for the following parameters: –density,–evaporation,–emulsification, and the stability of the emulsion formed,–dispersibility,–fitness for recovery by oleophilic means,–changes in composition and signatures,–….
Presented alongside this are other experimental simulation methods developed to determine the fate (medium- and long-term persistence) of a pollutant on different substrates in coastal environments. The initial results are then discussed.
Design, Benefits and Use of an Interactive Oil Spill Contingency Plan (i-OSCP)
Authors: Cavaye Nicholas , Poutchkovsky Alexis 
Published: December 2007

Abstract
This paper describes the interactive Oil Spill Contingency Plan (i-OSCP) which TOTAL E&P developed in partnership with OSRL. The i-OSCP is accessed via the organisation's intranet, and provides a procedural framework, information and tools to support personnel during an oil spill response. Using standard internet technology the i-OSCP incorporates interactive forms, and provides a simple means of accessing, recording and communicating information. Oil spill reports and other forms are completed on-line, distributed by e-mail and are used to update an incident status screen. Data from other sources within the organisation are incorporated, which saves duplication of information and improves integration with existing systems. Acceptance of the i-OSCP by the organisation has been rapid due to the ease of use. A key feature for the HSE department is the simple means by which data and forms can be modified or updated.
Steam Alternating Solvent Process
Authors: Zhao L. 
Published: December 2007

Abstract
A new heavy oil recovery process, Steam Alternating Solvent (SAS) process, is proposed and studied using numerical simulation. The process is intended to combine the advantages of the SAGD and VAPEX processes to minimize the energy input per unit oil recovered. The SAS process involves injecting steam and solvent alternately, and the basic well configurations are the same as those in the SAGD process.
Field scale simulations were conducted to assess the SAS process performance using typical Cold Lake reservoir conditions. These results suggested that in the field, the oil production rate of a SAS process could be higher than that of a SAGD process. The usually higher viscosity of the oil along the chamber boundary in the SAS process was largely compensated by higher relative oil phase permeability resulting from higher oil phase saturation. On the other hand, the lower oil viscosity in the SAGD process was balanced by lower oil phase relative permeability due to higher water saturation at the chamber front. Preliminary economic analysis indicated that comparing to the SAGD process, the SAS process might save 18% of the energy input for the same oil production.
Recognition And Significance Of Paleosoil Zones In A Heavy Oil Development Program
Authors: Johansen Steven J , Engstrom James C , Siemers W Terry 
Published: December 2007

Abstract
Several types of ancient soil zones are present in the reservoirs of the Hamaca Development Area, Orinoco Heavy Oil Belt of Venezuela. It is important to recognize these paleosoils when drilling production wells and when constructing reservoir simulation models. The major reservoir sands were deposited in fluvial and fluviotidal channel systems in Miocene strata that rest directly on Precambrian basement. A thick weathered regolith is locally present on basement. It is composed mostly of etched quartz and kaolinite, and in places bears the structure of the antecedent crystalline rocks. The intense weathering typical of ancient tropical soil processes has removed most radiogenic materials from these regoliths, so they have a gamma ray response similar to that of a reservoir sand. However, they drill extremely slow, using up valuable rig time, and probably will not contribute significant production. Unfortunately, they cannot be readily distinquished from good reservoir sands by seismic methods. Other types of paleosoils are present higher in the reservoir zone. These soils developed in floodplains and backswamps and are characterized by abundant illuvial kaolinite, precipitated siderite spherules, blocky soil peds, and pale colors. They often occur directly on top of channel and splay complexes, and are sometimes overlain by lignites or liginitic shales. These may also have subdued gamma ray response, making them difficult to recognize with MWD gamma ray tools, but their high irreducible water saturation is reflected in their low resistivity response. These paleosoils can contribute to seals and baffles within reservoir intervals, and can also complicate drilling by introducing slow-drilling, less productive zones within the reservoir. These can be recognized in some, but not all, instances with seismic data, when sufficient well control is also available.
Reservoir-Based Fracture Optimization Approach
Authors: Soliman M. Y. , Byrd Audis , Walters Harold , Weijers Leen 
Published: December 2007

Abstract
A new methodology to obtain the optimum fracture treatment design for a wide range of reservoir conditions has been developed and successfully implemented. The approach discussed here significantly reduces the time required to evaluate an optimum design and limits the materials considered to only those that are appropriate for the reservoir conditions. These improvements make it an ideal methodology for real-time re-design of fracture treatments after feedback from minifrac data has been implemented.
This innovative fracture design methodology has capability to determine appropriate fracture conductivity and an economic optimum fracture length while reconciling these with actual fracture growth behavior in the reservoir. The technique incorporates the following simple, automated steps: Selects the most cost-effective fluid that will meet a minimum apparent viscosity requirement at a specified shear rate and temperature condition from a large industry fluid library to ensure that the proppant will be placed within the pay zone.Selects a proppant that will provide the required fracture conductivity at the cheapest cost from a large industry library.Determines the proppant concentration that is required at the wellbore to achieve a user-specified dimensionless conductivity criterion for a range of fracture lengths.Evaluates economic criteria such as net present value (NPV) and return on investment (ROI) for different fracture lengths by comparing fracture treatment cost and revenues from production response.Determines the optimum fracture conductivity profile that will have a uniform pressure drop down the fracture. The conductivity is adjusted for potential losses from non-Darcy and multi-phase flow, gel damage, embedment, and other proppant damage effects.Iterates a fracture treatment schedule that will result in the best fit of the optimum conductivity profile.
The methodology can help optimize fracture treatments in any type of environment. The technique is simple and can be run quickly in a real-time environment after a minifrac is conducted to make changes to the propped fracture treatment. The procedure has been implemented in a commercially available fracture design program.
Mitigating Vibration in Bi-center Drilling Programs
Authors: Lapierre S. G. , Seiler N. , Chen D. C-K 
Published: December 2007

Abstract
Despite extensive investigation by the drilling and research community, vibration-related bottom-hole-assembly (BHA) failures are still common today. There are many theoretical forms of vibration that have been described in industry literature. Having to address multiple forms simultaneously, vibration mitigation procedures are often overly complex and ineffective.
An extensive study of high-resolution vibration data was undertaken to identify primary forms of destructive motion. Consistencies in BHA behavior were identified from this study and revealed that specific BHA's regularly demonstrate fundamental vibration tendencies in specific environments. As a result, a more focused procedure for corrective action has been adapted and implemented. This procedure has been proven effective without significant negative economic impact to the drilling operation.
This paper discusses the findings of the study. More specifically it addresses the destructive motion of bi-center assemblies. Data from two field examples will be highlighted for practical application.
Specialized Rig-Crew Training Produces Results for New Technology Drilling Rigs
Authors: Plageman Richard A. , Milliren Scott A. , Blackman J. D. 
Published: December 2007

Abstract
This paper describes a successful training program that bridged the gap between machine capabilities and human skills. The program was conducted in support of a land-drilling rig construction project utilizing leading edge technology in rig components and manufacturing techniques. The targeted training was designed to accelerate the learning curve and provide the rig crews a foundation of skills and knowledge that allowed them to excel beyond the company and industry expectations. The curriculum was developed in part from organizational learnings taken from previous new-build programs and from equipment manufacturers' recommendations and expertise.
The combined effect of focused training, organizational learning, and leading edge technology has lead to superior performance in the field. To date, the Total Recordable Incident Rate (TRIR) is 76% lower than comparable, in-house, new-build programs. Likewise, turnover is 70% lower than the past projects. Out of 169 wells drilled by these new rigs, 70% of all wells are below and 6% are on target with the customer's estimated drilling time.
A Deepwater Well Construction Alternative: Surface BOP Drilling Concept using Environmental Safe Guard
Authors: Simondin A. , MacPherson D. , Touboul N. , Ragnes G. 
Published: December 2007

Abstract
Over the recent years, the oil industry has been drilling wells in ever increasing water depths. Drilling these deepwater wells is performed under specific conditions namely a combination of extreme thermodynamic conditions (low temperature and high external pressure at the mud line level) and a narrow margin between pore pressure and fracturing pressure. These conditions lead to a number of drilling difficulties, especially in terms of well control.
Traditionally, these challenging wells are drilled using a sub-sea BOP stack connected at the mud line with a low-pressure riser to the surface. From a well control point of view, this configuration presents several limitations: BOP closing time may be long enough to allow part of the influx to migrate inside the riser, long kill and choke lines add significant friction losses which sometimes jeopardize the kick control, BOP components are subject to extreme thermodynamic conditions and therefore are prone to frequent failures which increase drastically the rig NPT.
In an attempt to overcome the drawbacks of using a sub sea BOP stack and reduce the costs associated with an expensive rig package, the industry developed a technique using the BOP stack on surface in a "jack-up type" configuration and a high pressure drilling riser. Primarily used in the Far East, this technique presents certain limitations, the main one being the absence of a secondary barrier at or just below the mud-line in case of riser failure.
Total was considering to use this technique in 2000m water depth on its recently-acquired Donggala deepwater block, offshore Mahakam straight, Indonesia. A Quantitative Risk Assessment on surface BOP stack drilling was performed. This highlighted the necessity to have a shut-off device at the mud line level in order to reduce the environmental impact in the event of riser failure. Total, in association with Cameron, designed and developed this sub sea shut-off device (hereafter referred to as ESG – Environmental Safe Guard) and with Transocean upgraded a rig to allow safe and efficient drilling on the Donggala block.
This paper outlines the development of the ESG in parallel with the required riser design and well architecture as an alternative to deepwater well construction. An operational feedback on the successful running of the ESG is provided.
Drilling Riser Management for a DP Drillship in Large, Rapidly – Developing Seastates in Deepwater
Authors: Brekke James N. , Soles Julian , Wishahy Momen A. , Stahl Matthew 
Published: December 2007

Abstract
In early 2003, the Glomar Jack Ryan dynamically-positioned drillship drilled a well in the Great Australian Bight in 4308 feet of water. This well was unique in that retrieval of the long riser was required in advance of large, rapidly-developing seastates. Accurate seastate forecasting and on-site measurements were key elements provided by the operator to ensure that enough time was allowed to have the riser pulled and on deck in case well-specific operating criteria were to be exceeded. These seastates were established based on discussions between operator and drilling contractor personnel supported by riser analysis results. Riser recoil analysis was a governing factor so extensive work was carried out to investigate the potential for damage to the BOP stack and slack in the tensioner lines in case of an emergency disconnect.
The subject well was the first drilled by a dynamically-positioned drillship in the Great Australian Bight since 1980. On this well, drilling operations were interrupted even more frequently than they would be otherwise as the well timing extended into the higher seastates of Australia's winter season. In the end, the well was successfully drilled despite encountering several instances in which the significant wave height was about 8 meters (26 feet). In each of these encounters, the riser had been pulled and was on the deck, as was called for by the riser management plan. This paper presents an overview of the riser management carried out for this well.
Drilltronics: An Integrated System for Real-Time Optimization of the Drilling Process
Authors: Rommetveit Rolv , Bjørkevoll Knut S. , Halsey George W. , Larsen Hans Freddy , Merlo Antonino , Nossaman Leslie N. , Sweep Miles N. , Silseth Knut Martin , Ødegaard Sven Inge 
Published: December 2007

Abstract
Drilltronics is the project name of a new and innovative system for drilling automation and simulation. The concept uses all available drilling data (surface and downhole) in real time to optimize the drilling process. If a sensor is failing (PWD for example) then advanced models mirroring the drilling process will calculate the parameter missing (pressure at the PWD sensor position). The system is composed of the following elements: Software modelling with algorithms that reflect the wellbore behaviour and its interaction with the drilling equipment. Currently under development are transient flow and heat transfer models, a drillstring torque and drag model, weight on bit optimization, and stick/slip analysis.The models are driven in real time by drilling data that are logged at high acquisition rate. The system is continuously calibrated through analysing the data with advanced filtering techniques.Real-time diagnosis of the drilling process is obtained from comparing measured data with model predictions. This makes up a basis for continuous adjustments to the drilling strategy.An integrated drilling simulator is developed by linking the modules together, and combining it with an ROP model. This can be used for pre-planning, sensitivity analysis during drilling, post-well analysis, and training objectives.Selected, critical sub-operations will be automated for fast and reliable reaction, e.g. automatic control of the drawwork based on dynamic surge and swab calculations, and automatic detection and first action after easily recognised symptoms on hole problems like pack off or stuck pipe.
In order to realize the full potential of Drilltronics, surface and downhole drilling data must be available in real time. The drilling equipment will need to be computer controlled with an interface that supports automatic responses to the model's analysis.
Advances in API/ISO Oil Mud Chemical Analysis Field Procedures
Authors: Smith Martin V. , Morton E. K. , Pless Marvin L. , Ray Randy , Shumate Thomas , Toups John 
Published: December 2007

Abstract
Oil-based and synthetic-based drilling fluids are important to the industry because they provide excellent performance under the most difficult drilling conditions. To maintain the integrity of these systems, engineers depend upon field test procedures contained within API RP 13B-21 (ISO/FDIS 10414-22). An API Work Group has recently improved these procedures by enhancing reproducibility and substantially reducing standard deviation. This paper will describe the methods and data used to achieve these significant gains.
Barite-Sag Management: Challenges, Strategies, Opportunities
Authors: Scott Paul D. , Zamora Mario , Aldea Catalin 
Published: December 2007

Abstract
Barite sag continues to be a recurring, potentially serious problem on many directional wells. Despite concerted efforts by the drilling industry and early progress, recent continued improvements in sag mitigation have been limited. Sag is a particular problem on HTHP wells and in deepwater wells where ECD management is required. These wells pose difficult drilling conditions where drilling practices may offset sag-management advancements.
The sag "magic bullet" has thus far been elusive. This is understandable since sag is affected by many parameters and their interactions are difficult to quantify. While the importance of mud rheology is well known, attempts to find the key rheological parameter have not been completely successful. Furthermore, lack of industry standards to measure and report barite sag has limited the availability of usable field data. Sound engineering strategies and guidelines have helped, but clearly more developments are needed.
The primary objectives of this paper are to (a) examine key barite-sag challenges, (b) characterize current best practices, and (c) discuss strategies, opportunities, and active programs for step improvements. Recent barite-sag case histories from the Gulf of Mexico, West Africa, and Atlantic Canada are included to set the proper perspectives.
Modeling of ECD in Casing Drilling Operations and Comparison with Experimental and Field Data
Authors: Diaz H. , Miska S. , Takach N. , Yu M. 
Published: December 2007

Abstract
Three modeling approaches to the determination of equivalent circulating density (ECD) in Casing Drilling1 operations are considered in this study; viz., hook-load measurements, pump-pressure measurements and conventional hydraulic models. The bottom-hole pressure is obtained by adding the calculated annular pressure losses to the hydrostatic pressure. Since the annular clearance is very small in casing drilling, a narrow-slot flow approximation model is adopted that takes into account the effect of pipe rotation. A Yield-Power-Law (YPL) drilling fluid is considered in this study.
Results from each of the three approaches are compared with experimental and field data. The differences between the calculated and measured bottom-hole pressures (hence ECD) are within a range of about ±8%. In terms of the frictional pressure losses in the annulus, this range increases to about ±60% in some instances.
It is shown that pipe rotation plays an important role in determining ECD. The experimental data indicate an increase in the annular pressure losses with increasing pipe rotary speed. The hook-load measurements correlate well with flowing bottom-hole pressures.
Cementing Deepwater, Low-Temperature Gulf of Mexico Formations Prone to Shallow Flows
Authors: O'Leary Jim , Flores Juan Carlos , Rubinstein Paulo , Garrison Greg 
Published: December 2007

Abstract
Shallow gas and water flows are a major concern when cementing deepwater wells in many Gulf of Mexico fields, often requiring expensive remedial work, premature well abandonment and respudding. Entire templates can be compromised if a single cement job on surface pipe fails to provide zonal isolation from the shoe up to the mud line.
Traditionally, compressible fluids (mainly foamed cements containing nitrogen) have been used to mitigate shallow-flow hazards in the Gulf of Mexico1. The disadvantages of these systems include safety concerns, complicated logistics, lack of reliability, placement problems, and lack of confidence in long-term cement integrity.
As an alternative to standard energized fluids, special cementing systems based on packing volume fraction and ratios of sized particles (particle-size distribution or PSD systems) have been used with success in water depths exceeding 6,000 ft in the Gulf of Mexico. This paper provides case histories and discusses the use of these innovative systems for deepwater situations. These systems are specially designed to provide optimized gel and compressive-strength development in low-temperature environments while allowing the thickening time to be tailored to any wellbore geometry. Slurry volumes from 1,500 to 2,500 bbl have been pumped without incident. The intrinsically low permeability and porosity of these systems at both the slurry and set-cement stages provide resistance to external attacks and influx of water or gas. In addition, these systems are tested and pumped using standard equipment, completely avoiding the complications of energized fluids; extra personnel are not required.