bluuebunny/crossref_metadata_2025_split huggingface dataset:
Balancing Environmental Tradeoffs Associated with Low Impact Drilling Systems to Produce Unconventional Natural Gas Resources
Authors: Haut Richard C. , Burnett David , Williams Tom , Theodori Gene 
Published: February 2011

Abstract
An environmental scorecard has been developed to determine the tradeoffs associated with implementing low impact drilling technology in environmentally sensitive areas. The scorecard assesses drilling operations and technologies with respect to air, site, water, waste management, biodiversity and societal issues. Low impact operations reduce the environmental footprint of operations by the adoption of new methods to use in (1) getting materials to and from the rig site (site access), (2) reducing the rig site area, (3) using alternative drilling rig power management systems, and (4) adopting waste management at the rig site. The scorecard enables a dialog to be established and maintained among all interested, concerned and affected stakeholders. In this manner, the industry has a new way of seeing itself within the larger network. The scorecard that will be presented in the paper provides the means to demonstrate the connectivity between energy production and the affected ecosystem. The Houston Advanced Research Center (HARC) is leading a consortium effort to investigate the development of low impact drilling systems. The work originated in 2005 and funding was obtained by the U.S. Department of Energy for 2006 – 2009. Additional funding for the effort was obtained through the Research Partnership to Secure Energy for America (RPSEA), industry and environmental organizations. The goal of this project is to reduce the environmental impact of rig operations through integration of low-impact site access and site operations. The paper discusses the scorecard that is being developed. The scorecard methodology presents an ecological understanding of the tradeoffs associated with producing energy. The scorecard methodology was developed through a series of workshops being held with ecologists, botanists, wildlife management experts and others in addition to oil and gas industry experts.
Geostatistical Modeling and Numerical Simulation of the SAGD Process: Case Study of an Athabasca Reservoir With Top Water and Gas Thief Zones
Authors: Bao X. , Chen Z. J. , Wei Y. , Sun J. , Dong C. C. , Deng H. , Song Y. 
Published: February 2011

Abstract
Overlying top water and gas thief zones have a detrimental effect on the Steam-Assisted Gravity Drainage (SAGD) recovery process since steam penetrates into these zones which results in great heat loss. Due to the presence of these top thief zones, recovering bitumen by the SAGD process has become challenging in the Surmont lease of an Athabasca oil sand reservoir.
Previous numerical simulations, laboratory experiments and field production data have demonstrated that oil production and steam-oil ratios tend to decrease as the depletion of top gas continues; also, heat loss to the overlying thief zone will be more significant when a top water zone is present. However, an optimal operating strategy for the full field scale SAGD process with both top gas and top water remains uncertain.
The objective of this paper is to construct a 3D geostatistical model for a Surmont pilot and implement sensitivity study in SAGD simulation aiming at investigating the impact of the top thief zones on bitumen recovery. The major steps involved in the 3D geostatistical modeling process consist of structural, facies and property modeling and uncertainty analysis. Facies-based log-derived porosity, permeability and water saturation are populated into a grid block by Sequential Gaussian Simulation (SGS) in the petrophysical modeling process. Then a static model is further downscaled to finer simulation grids, and a submodel for each single well pair is extracted for the purpose of history match in the STARS™ simulator.
Reasonable history match of oil and water rates has been achieved by calibrating this static model with field production data. The steam chamber pressure and temperature profiles from the numerical model have been conformed to the field data from the observation wells. Sensitivity analysis of the thief zones pressure, thickness and area extension has been conducted to simulate the impact of the top thief zones. Optimization of cumulative steam oil ratios (cSOR) and recovery factors by varying the steam trap control and injection pressure with the top thief zones has been investigated in great detail. Finally, integrated optimization strategies have been developed and tested on a full field-based heterogeneous simulation model.
Corrosion Management of a Worldwide Existing Pipeline Network
Authors: Bonis Michel 
Published: February 2011

Abstract
This paper first describes a semi-quantitative methodology for assessing the corrosion likelihood of existing production pipelines which was developed by the Company and applied over its worldwide operations.
This methodology is based on a quantitative answer to three key practical questions, requiring the involvement of key personnel aware of the past and current operating conditions of each line.
This assessment, carried out on a yearly basis for each subsidiary, is now in its third year and has quickly gained credit from all interested parties, and especially the operating entities of the Company throughout the world.
In a second part a detailed review of the few pipeline failures and of all intelligent pigging results experienced during the last 5 – 8 years is summarized.
It is shown that external corrosion of onshore buried lines and of the aerial section of offshore risers are the two main corrosion issues. A more systematic inspection is the best answer to this problem, although some progress is also needed on the design side. On the other hand, it is shown from numerous cases and examples that internal corrosion of pipelines can be well mitigated over several dozens of years, as long as relevant personnel is aware of (and even preferably "frightened by"…) the possibility of such internal corrosion inside their pipes. As above, there is no better way than inspection to provide this awareness as well as to document the efficiency of mitigation methods.
Last but not least, this review gives access to detailed average corrosion rates for most corrosion modes involved, which can then be used to better assess the Corrosion Likelihood of any pipeline and to adjust inspection frequencies.
Reliable Connectivity Evaluation in Conventional and Heavy Oil Reservoirs: A Case Study From Senlac Heavy Oil Pool, Western Saskatchewan
Authors: Kaviani D. , Jensen J. L. 
Published: February 2011

Abstract
Evaluating interwell connectivities can provide important information for reservoir management by identifying flow conduits, barriers, and injection imbalances. The multiwell productivity index (MPI)-based method is a recently-developed tool to infer interwell connectivity based on injection/production data. Previously, the MPI method worked well when tested on several synthetic cases under ideal conditions. In this paper, we show the application of the method on a field case, the heavy-oil Senlac field in Saskatchewan.
Nonideal but common conditions, such as the unavailability of injector and producer BHP's and short term and frequent producer shut-ins, may have a large affect on the results of the MPI method. By using the similarities of the MPI method and another connectivity evaluation procedure, the capacitance model (CM), we define a new connectivity parameter that is less sensitive to nonideal conditions. Dramatic changes of the mobility ratio in heavy oil fields still affect the performance of the model but, by applying a dynamic multiwell productivity index, we reduce this problem. Temporary shut-in of the producers within the sampling interval also leads to less accurate estimation of connectivity parameters and production rates. By applying an equivalent skin model and using the average rate formula, we can overcome this problem.
Compared to connectivity parameters defined in previous studies, the one defined here is more robust and less sensitive to the specific circumstances that are common in field cases. The dynamic model suggested in this paper helps us to model cases with variable mobility ratios more accurately. Applying the modifications suggested here improves the fit between predicted and actual production. Using the new connectivity parameters in Senlac, we observed good agreement between the connectivity map and the geological features of the reservoir.
The procedures and modifications described in this paper enable us to use the MPI method more effectively in field cases with common nonideal conditions, including heavy oil waterfloods. Insensitivity of the model to changing well conditions provides a more versatile tool to analyze field data. Furthermore, if we choose to use the CM instead of the MPI, we find that using information from the MPI can benefit the application of the CM. Applying these approaches, we can have a more reliable understanding of the reservoir heterogeneity and quick prediction of reservoir performance to optimize the waterflood.
Record-Setting Horizontal Pilot Wells Drilled and Completed to Establish Feasibility of Developing Giant Offshore Field from Artificial Islands
Authors: Jorden John , Keller Stu , Al Junaibi Hamad Saleh 
Published: February 2011

Abstract
This paper summarizes the planning and execution of the well construction and completion of two pilot wells in a giant oil field offshore Abu Dhabi. These wells are an injector-producer pair batch drilled by a jack-up rig from a wellhead platform tower (WHPT). The wells have measured depths of approximately 20,000 ft and a 10,000-ft horizontal reservoir section. The main objective of drilling these wells is to establish the feasibility of developing the field using extended-reach wells drilled from artificial islands instead of the current scheme of using WHPTs.
The wells set a number of records and firsts, including: Longest measured depth well drilled offshore Abu DhabiDrilling the longest horizontal reservoir interval offshore Abu DhabiInstalling the world’s longest high-hole-density preperforated completion linerFirst use of non-aqueous drilling fluid (NAF) offshore Abu DhabiFirst use of a scale-preventing sodium chloride/sodium bromide reservoir drill-in fluid offshore Abu Dhabi
One of the main drilling challenges was the need to drill a weak shale formation at high angle (&gt; 60 degree) and smoothly land the well at a 90-degree inclination in the target reservoir. This was addressed by performing a Fast Drill Borehole Management study to identify the optimum drilling parameters (e.g., mud weight, flow rate) and by use of NAF as well as optimum operational practices. This first use of NAF offshore Abu Dhabi required extensive rig modifications and the transport of cuttings to shore for cleaning and disposal.
One of the main completion challenges was to compartmentalize the 10,000 ft reservoir interval into segments for reservoir management. This was achieved by using a pre-perforated liner run with ten swell packers in each well. The liner perforation size and pattern were designed to ensure effective stimulation access while minimizing risk of liner damage due to installation loads.
Another challenge was acid stimulation of the completion interval which had a pore pressure greater than 1.2 sg (10.0 ppg) due to offset injection wells. To address the stimulation challenges, a 22,000-ft, 2-3/8-inch coiled tubing string was designed and fabricated.
The paper addresses a number of aspects of the planning and execution of these ERD pilot wells, including Well design, including well path planningDrilling fluidsRig modificationsCompletion designStimulation planningBatch drilling operationsNAF cuttings managementDirectional drilling performanceCompletion liner runningPlans for future pilot wells
Natural Gas Potential in the Saint Lawrence Lowlands of Quebec: A Case Study
Authors: Lavoie Jean-Yves , Marcil Jean-Sebastien , Dorrins Peter K. , Lavoie Jeremie , Aguilera Roberto 
Published: February 2011

Abstract
Since the announcement made in April 2008 concerning the shale gas potential of the Southern Quebec Lowlands, almost 15 new wells have been drilled in the area. The calcareous and organic-rich Middle Ordovician Utica Shale is the main target of this recent exploration effort. Current knowledge of the area's geology have led operators subdivide the shale gas potential into different play types. To date, most operations have been performed in approximately 1/3 of the shale basin in the medium to deep thermogenic shale gas play (1,000-2,000 meters), located in the central part of the Saint Lawrence Lowlands. With OGIP estimates ranging from 120 to 160 Bcf per section, the deep play is considered to be promising. Current efforts focus on determining the highest gas prone unit within the Utica. The remaining 2/3 of the shale basin has not been largely tested yet, but the potential remains promising.
Based on exploration work carried out over the past five years in Southern Quebec, four other play types have been described: 1) shallow to medium depth thermogenic shale gas; 2) overthrusted shale gas; 3) biogenic shale gas; 4) Intra-Appalachians sub-basin shale gas. They are less explored than the deep shale play, but also present interesting potential.
This paper describes the above mentioned plays using basin geology, shale mineralogy, organic matter type, gas geochemistry, structural style and infrastructure access. The characteristics of the above plays are reviewed from geological, geochemical, structural and production perspectives. Results of evaluations using the concept of flow units, and volumes of original-gas-in-place calculated by various organizations are compared with a recent evaluation using the Petroleum Resources Management System (PRMS).
It is concluded that there is promising hydrocarbon potential in the Saint Lawrence Lowlands of Quebec that continue to stimulate operators to pursue the exploration and development of these plays.
An Experimental Investigation Of In-Situ Combustion in Heterogeneous Media
Authors: Awoleke O. G. , Castanier L. M. , Kovscek A. R. 
Published: February 2011

Abstract
In-situ combustion (ISC) is an intriguing yet complex method of enhanced oil recovery due to the interplay of air flow and oil reactivity. This paper presents the results of a recent experimental effort to shed more light on the ISC process by investigating the effects of different scales of porous medium heterogeneity on ISC. We probed the effects of pressure, temperature, injection rates and matrix properties on the combustion of Middle-Eastern 19.7° API and a Californian 16° API crude oils. The experimental perspective includes both oil oxidation kinetics and combustion-front dynamics in a 1-m long combustion tube. After establishing successful combustion in homogeneous media, we proceeded to investigate the effect of heterogeneity on the ISC process by conducting combustion tube runs in a gravity-stable mode. From the experimental data, pre and post-burn CT scans, and postmortem analysis, we deduced the effect of both small and large-scale heterogeneities on the spatial and temporal propagation of the combustion front. The combustion front traveled unhindered through sections of the combustion tube containing heterogeneous packing with length scales on the order of centimeters. On the other hand, it was more difficult to obtain successful front propagation in media with heterogeneities on the order of tens of centimeters. The ISC process was probably challenged by the relatively fast transport of air through high-permeability zones and the relatively slow transport of the much-needed air through low permeability sandstone thereby effectively starving the burning front of oxygen, and extinguishing the process in this case.
Seismic Source Parameters Optimization in Shallow Water Area Offshore Abu Dhabi, U.A.E.
Authors: Ishiyama Tomohide , Painter Derrick , Belaid Kamel 
Published: February 2011

Abstract
Seismic source parameters are one of the important specifications for a seismic survey. Conventional thinking is that larger sources produce higher energy, and thereby improve data quality. However, in shallow water areas offshore Abu Dhabi, United Arab Emirates (U.A.E.), the source size is limited due to operational constraints such as shallow water depth and several scattered production facilities.
To address these issues, a pilot seismic survey was acquired in a shallow water area with the main objectives: to determine data quality versus source parameters; and to optimize source parameters for future seismic surveys. In this survey, several datasets were acquired with different source parameters, however, using the same source vessel and air-gun array. Then, data quality for each dataset was evaluated at various processing stages.
We show that shorter shot-point interval (SPI) and appropriate processing, e.g. noise attenuation in a domain with a closer trace interval, could compensate for a lack of source energy, then even a small source could achieve the required data quality with the aid of suitable SPI and processing. The results should encourage investigating even smaller sources which are easier for the operations and friendlier to the environment.
Developed Approach for Better Understanding of Low Resistivity Pay Carbonate Reservoirs
Authors: Obeidi Adel , Aryani Fatema Al , Amoudi Mohsen Al 
Published: February 2011

Abstract
Some of the Middle East UAE lower Cretaceous Thamama Carbonate reservoirs are characterized by low resistivity pay phenomena, on which log analysis results in high water saturation computation; on the contrary, production tests confirm dry oil.
The Sedmintological investigation on thin sections have shown significant percentage of Micro-porous (occluded porosity or non-efficient porosity) network traps irreducible hyper-saline formation water which responds to a low resistivity, even if the oil is occupying the larger size of porosity (efficient porosity).
This paper presents a simple and cost-effective approach for better identification and evaluation of low resistivity pay carbonate reservoirs. The approach utilizes the pulsed neutron capture log (PNCL) in real-time logging in proper identification and formation evaluation in these reservoirs through case studies in the Middle East-UAE Carbonate reservoirs.
Through number of wells that have recently been drilled using different types of mud and were logged by LWD PNCL; the results have clearly shown the benefit of minimizing evaluation uncertainties compared to those logged without LWD PNCL.
For decades, the combination of conventional logs i.e. neutron, density and resistivity are undoubtedly proven technologies to evaluating homogenous reservoirs. Unlikely, accurate determination of Petrophysical parameters and water saturation evaluation would rather be difficult to show especially in so-called low resistivity pay reservoirs. Since the PNCL (Sigma log) provides a resistivity independent water saturation evaluation, the PNCL has become an integral part of the evaluation program in these low resistivity pay reservoirs, particularly using OBM with relatively high rate of penetration, so that well bore surrounding environment would not be greatly altered (minimum invasion). LWD drill and wipe passes evidently demonstrate that the different between logs can be caused only by reservoir fluid change.
Multistage Fractured Cardium Oil: Studying Geology and All of the Production and Stimulation History Thus Far
Authors: Leshchyshyn T. T. 
Published: February 2011

Abstract
As the industry has unlocked vast new resources in North America with multistage fractured horizontal wells, an immense push has occured in terms of applying these new technologies to new plays. In the last 3 years, there has been an immense development in the Cardium tight oil play in Alberta, Canada, as commodity prices have encouraged a shift to oil exploitation whereever possible. A variety of operators and service companies have employed many differing techniques which have evolved over the years, to attempt to maximize Cardium oil production and reserves.
ALL public well files for ALL fractured horizontal wells have already been collected from the public realm regardless of the operator and service company. leading up to the abstract submission date with select wells added up to manuscript deadline date. These files are currently being reviewed and tied to production to establish empirical results and evolution in the exploitation of this play. Factors currently being examined are isolation technologies, stage spacing, frac fluid selection, proppant selection as well as a variety of other information.
A large amount of geological information will be reviewed and presented in order to understand the production expectations as a part of a regional study of various geological properties. When possible, a combination of geological and stimulation information will be examined together.
Whole Core Versus Plugs: Integrating Log and Core Data to Decrease Uncertainty in Petrophysical Interpretation and STOIP Calculations
Authors: El Din S. Serag , Dernaika M. R. , Al Hosani I. , Hannon L. , Skjœveland S. M. , Kalam M. Z. 
Published: February 2011

Abstract
Most carbonate reservoirs are commonly characterized by multiple-porosity systems that impart petrophysical heterogeneity to the gross of reservoir interval. Hence, the specific types and relative percentages of pores present, and their distribution within the rocks, exert strong control on the production and stimulation characteristics of carbonate reservoirs.
The impact of heterogeneity on core and log measurements is assessed. The challenge is to determine the reliability of relatively small scale properties measured by a log or core to the large scale reservoir property. A related question is one of reconciling the variability seen in high resolution (small volume of investigation) measurements (e.g. core plugs), with the variability in relatively low resolution (large volume of investigation) measurements (e.g. wireline log).
Routine and SCAL laboratory measurements on carbonate core samples from prolific reservoir in Abu Dhabi. The measurements were conducted on different scale samples ranging from small trims to full diameter whole core samples. Porosity and permeability obtained from small trims, plugs and whole core samples were compared with log data to study the impact of the measured volume on the results. Electrical property measurements were performed on 1.5" diameter plugs and 4" diameter whole core samples to evaluate the impact of heterogeneity and volume scale on cementation factors which are essential for proper petrophysical interpretation and saturation calculations.
Different scale measurements showed variations in both Routine and SCAL data and emphasized the importance of the whole core measurements in representing reservoir heterogeneity which could be used to better evaluate resistivity logs. Plug scale Poroperm data; however, were important in capturing higher degree of reservoir heterogeneity. The better integration between core and log data and the use of the right electrical parameters in petrophysical interpretation tends to minimize the uncertainty in STOIP calculations.