bluuebunny/crossref_metadata_2025_split huggingface dataset:
Physical Water Treatment in the Oil Field: Field Results from Indonesia
Authors: Muswar Heppi , Parker Wiley , Falsini Francesco , Thaib Dirasani 
Published: February 2011

Abstract
Oil and gas wells in the Wampu field in Indonesia are plagued with carbonate scale depositsi. These deposits interfere with efficient oil and gas production from these wells and limit their profitability. Electromagnetic physical fluid treatment is a new strategy for controlling deposits and this paper describes both the theory behind the treatment strategy and the compares results of 18 months of application on wells in this field with that previously seen. Comparison results will be presented from wells in North America.
Who Gets to Be Boss? … addressing demographic pressures within the petroleum industry
Authors: Lau Richard A. , Hasani Nadia Al , Lau Laura , Eide Constance 
Published: February 2011

abstract
From the day in 1859 that Edwin Drake drilled the first oil well in Titusville, Pennsylvania, English has been the lingua franca of the petroleum industry. As the quest for oil escalates into all areas of the world and as solutions to the world's energy needs become more complex, national and international oil companies compete to employ the best and brightest to ensure that the flow of precious hydrocarbons remains unabated.
The Abu Dhabi National Oil Company (ADNOC) in the United Arab Emirates (UAE), a state-owned petroleum producer that boasts some of the largest known oil reserves on the planet, perpetually finds it difficult to employ enough qualified English-speaking staff to manage its petroleum exploration, production, and distribution subsidiaries. Concerned about its inability to fill positions locally, ADNOC has attempted many local initiatives and has even been compelled to provide scholarships for Emirati citizens to be educated in institutions of higher learning in North America, Europe and Australia. Nevertheless, this national oil company has been forced to import expensive, qualified engineers from abroad. (Geologists, 2008).
Grateful for employment as well as a safe environment to raise their families, many of these foreign engineers have remained and prospered in the UAE while accepting second-class status in a land they can never really call their home. Many of these professionals are now clamoring, however, for opportunities for their own children to be able to remain and become educated into the petroleum professions on a fairer footing.
Systematic Team Approach to Product Development Delivers Massive Performance Improvements in the Horn River Shale Gas Play
Authors: Barton S. P. , Lockley J. R. , MacLeod A. M. 
Published: February 2011

Abstract
The Horn River Basin is a natural shale gas play located in North Eastern British Columbia, Canada. However, these wells require advanced horizontal drilling techniques and extensive hydraulic fracturing to make them economically attractive. This paper details how a major operator, working in cooperation with a key drill bit supplier, has been able to make radical improvements in drilling performance in this area, leading to significant cost reductions.
A typical well consists of a main hole interval that has a vertical section, build section (taking the bore from vertical to horizontal), and a final horizontal leg. When the operator started this project in 2008, the objective was to drill this entire main hole in just three bit runs; one for each directional leg described prior. In actuality, twelve to fourteen bits were utilized, averaging over forty days from drill-out to section TD. This made the economic viability of further development questionable.
The team approach of operator and bit supplier enabled bit design modifications and improvements to be implemented in a controlled, continuous, and closely monitored program. A key component of this was the development of a unique flexible bit design developed specifically for directional applications in coordination with a leading supplier of motors. These bits contain novel features that allow rapid design modifications to be performed locally, significantly reducing response time, and allowing the program to proceed at a much faster pace than previously possible. Prior to any alterations, a full analysis of the drilling data of the previous iteration was undertaken. Any proposed changes were then discussed in detail with the drilling operations team, prior to implementation.
By July 2009, this systematic cooperative approach enabled the operator to achieve the initial objective of drilling the interval in 3 bit runs, but also their subsequent objective of drilling the interval in just two bit runs. Days to drill this section were drastically reduced from over forty to less than twelve days. The savings produced by this huge improvement in drilling performance has greatly assisted the economic viability of continued Horn River Basin development.
Electronic Rollerboard in Dispersed Engineering Execution
Authors: Soman Bhavna 
Published: February 2011

Abstract
The Electronic rollerboard (ERB) is a network based tool which allows users located in different offices across the globe to view, review and add comments to a document/drawing during the execution of a project. It delivers upto-date information to all involved. This paper talks about the various features of ERB and how they enable multiple offices to better execute projects together, by providing everyone with up-to-date information. It discusses how the ERB streamlines communication, which in turn facilitates change management, leading to better scheduling, and thus, significant savings for a project. The challenges in its setup and application to a project, shortcomings, and areas for future improvements are also addressed. This paper also shares possible software platforms through which the ERB can be implemented, and experiences from using it on a project.
Integrated Operation User Experience Starts with Data Flagging
Authors: Flichy Philippe 
Published: February 2011

Abstract
Complaints about the usability and trustworthiness of data along with their proper reconciliation and consistency checks have been an ongoing source of frustration to the effective adoption of the Digital Oil Field. Valid data is just the first step in the Digital Oil Field (DOF) data supply chain; once the data has been validated, it must then be properly stored (again), transmitted, accessed, and then displayed appropriately and in context.
This is where standards like PRODML play a pivotal role in facilitating multivendor applications interconnection. Until we have a better approach for validating and accessing the massive amount of data generated by new sensor technologies, we cannot reap the true benefit of either the technologies or processes of the DOF.
This paper attempts to highlight some similarities in the challenges other industries, such as aerospace and defence, are facing compared to O&G in terms of real-time data capture, visualization, and how are addressing them.
Capillary Trapping in Water-Wet Sandstones: Coreflooding Experiments and Pore-Network Modeling
Authors: Pentland Christopher H. , Tanino Yukie , Iglauer Stefan , Blunt Martin J. 
Published: February 2011

Abstract
Displacement experiments using the porous plate method were conducted on water-wet sandstones to measure the capillary trapping of oil by waterflooding as a function of its saturation after primary drainage. Three sandstone samples ranging in porosity from 12.2% to 22.1% were considered. Experiments on two samples were conducted at an elevated temperature and back-pressure of 343K and 9MPa respectively; experiments on the third sample were conducted at ambient conditions (292 to 297K and 0.06 to 0.17MPa). Residual oil saturation increases monotonically, but with a decreasing gradient, as initial saturation increases.
The dependence of residual saturation on initial saturation is accurately predicted by a two-phase pore-network simulator when a uniform distribution of intrinsic contact angles between 35° and 65° is assumed. The networks were extracted from X-ray microtomography images of small samples of the same rock as those used in the experiments. The laboratory measurements are also accurately described by trapping models proposed by Land (1968) and Spiteri et al. (2008). The residual saturations we measured were higher than in previous displacement experiments, suggesting, for example, that capillary trapping may be an effective way to store substantial quantities of carbon dioxide in aquifers.
Returns Matching Reveals New Tools for Fracture/Reservoir Evaluation
Authors: Gdanski R. D. , Fulton D. D. , Johnson B. J. 
Published: February 2011

Abstract
Evaluation of fracturing treatments in tight-gas sands is frustrated by uniqueness problems when matching gas rates and bottomhole-flowing pressure (BHFP) data alone. A fit-for-purpose simulator was used to match gas rates, BHFP, cumulative produced water, and composition of the water during five days of cleanup after a fracturing treatment. The simulator models physics of flow and chemical physics to provide improved history matching of the cleanup process. Downhole gauges were in place during cleanup and a 16-hour, shut-in period. History matching of the well returns data with the fracture cleanup model provided multiple solutions when matching gas, water, and BHFP. These solutions all fell on a “line-of-solutions” using a special plot of reservoir properties vs. conductive length. Pressure transient analysis (PTA) of the gas rate and BHP during cleanup and buildup provided solutions that also fell on the same “line-of-solutions.” A “root-of-time” plot of the 16-hour buildup indicated a fracture of infinite acting conductivity and no fracture face-skin damage. A “productive proportion” plot of the simulated fluid recovery vs. the ratio of conductive to created length was used to help narrow, or break, the uniqueness problem in the line-of-solutions. These tools demonstrated that the conductive length was roughly 400 ft. The reservoir permeability to gas was much lower than expected and was the cause of the disappointing productivity. This work demonstrates that matching well-return compositions with a fracture-cleanup model capable of chemical physics can lead to improved interpretations of both reservoir properties and fracture structure. Three new graphical tools provided compelling evidence for the interpretation, and should have significant value in future evaluations.
Costs of CO2 Transport and Injection in Australia
Authors: Neal P. R. , Hou W. , Allinson W. G. , Cinar Y. 
Published: February 2011

Abstract
This paper reports estimates of the costs of CO2 transport and storage across Australia. The estimates were commissioned as part of the work of the Australian Government's Carbon Storage Taskforce. Using data provided by government departments and industry, we investigated combinations of nine emission hubs and twelve storage basins. We also developed a first-pass method for estimating numbers of injection wells using numerical reservoir simulation and comparisons with actual CO2 injection projects.
This work forms part of a suite of studies intended to help formulate government policy on carbon capture and storage. Our analyses are aimed at helping industry and government to plan carbon abatement strategies by indicating regions likely to have lower deployment costs for CO2 transport and injection.
We present engineering and economics results for projects across Australia and rank storage basins by cost. The cheapest cases store CO2 from the Latrobe Valley in the Gippsland Basin (A$7 per tonne of CO2 avoided), from Southern Queensland in the Surat Basin (A$ 12 per tonne) and from the Perth region in the Bunbury Trough of the Perth Basin (A$10 per tonne). We include sensitivity analyses examining the effects on project costs of monitoring and exploration costs. We also show the results of analyses of the effect of exploration risk.
We provide recent estimates of CO2 transport and storage costs for potential projects across Australia on a consistent basis. These illustrate the importance of various geological characteristics in determining the CO2 injection cost, and report the relative costs of exploration, equipment, construction and monitoring. Finally we describe a quick and efficient first-pass technique for estimating well numbers.
Crosslinked Acid as an Effective Diversion Agent in Matrix Acidizing
Authors: Runtuwene Michael , Fasa Muhammad Hilmi , Rachmawati Fitria Dewi , Wijanarko Muhammad , Kadarsyah Arief , Komalasari Novi , Gurnito Nuratas 
Published: February 2011

Abstract
Matrix acidizing has been a successful stimulation method to enhance production in carbonate reservoirs. One of the challenges is to distribute the acid evenly along the interest zone to achieve a maximum stimulation effect, due to the differences in porosity, permeability and degree of damage along the interest zone.
Well-S delineation gas well, located in Senoro Field Sulawesi-Indonesia, is drilled through a carbonate reservoir. It was decided to use an acid soluble diversion agent instead of conventional proppant. This diversion agent is an acid system that contains a polymer that crosslinks as the acid spends to near completion, with this crosslink then disappearing as the acid spends more completely over time. The non-crosslinked spent acid can then be flowed back from the formation with relative ease.
Acid solubility test for 15% HCl and crosslinked acid was performed to design the acid job and the result showed that Senoro carbonate has 90% solubility. This crosslinked acid serves as a diversion agent that will facilitate the acid to be evenly distributed along the interest zone. The well test result before stimulation was 13 MMSCFD gas with skin value of +3 (obtained from PBU test), while permeability was 4 md. The well was tested again after stimulation. Significant increased gas rate was observed while the skin damage decreased.
This paper describes the planning and implementation of crosslinked acid application as an effective diversion agent in long interval matrix acidizing stimulation. Furthermore, it explains the criteria to determine the efficiency of this application.
Formation Evaluation Challenges in Thin Bedded Reservoirs: How to Effectively Test This Formation?
Authors: Kiatpadungkul Wiriya , Daungkaew Saifon , Athichanagorn Suwat , Azam Mohd Nor , van Doorn Jurry , Haddad Sammy 
Published: February 2011

Abstract
Thin beds are a prominent feature in many recently discovered hydrocarbon reservoirs around the world. Not only are they typically difficult to evaluate, which leads to high reserves uncertainty, they are also frequently associated with inconsistent well performance. One of the main challenges in the evaluation of thinly-bedded reservoirs is an accurate productivity assessment. High-resolution borehole image logs provide us with detailed information on the internal structure of reservoirs sands, sand quality indications as well as a net-to-gross determination. Reliable formation evaluation requires further high-resolution petrophysical and geophysical logs (for an initial permeability estimation, free fluid volume, saturation, formation anisotropy and structural information). However, as per reservoir testing information (pressure, fluid types, PVT properties, permeability and producibility), this dynamic reservoir characterization method needs to be properly planned and evaluated. In the past, the use of full scale Drill Stem Test and Production Tests were conducted to obtain reservoir parameters including zone productivity. However, due to costly operations especially in marginal and also deepwater reservoirs, different scales of pressure transient test have been introduced1, 2, and 3. Several publications have discussed the use of smaller scale testing to obtain reservoir information. However, there have been no publications showing a complete comparison of pressure transient data obtained from several scales of measurement when heterogeneity is present in the reservoirs.
This paper therefore aims to present a comparison of results obtained from alternative formation testing methods in a relatively thin (ten of meters) formation which are a single probe Wireline Formation Tester, dual packer Wireline Formation Tester, and full scale well test. This paper also discusses ways to optimise the testing methodology in such thin reservoirs. The application of an Interval Pressure Transient Test (IPTT) using a single probe as well as the dual packer WFT are illustrated and discussed in details. Their applications, specifications, advantages and disadvantages over the conventional testing method are extensively covered. This study aims to aid in devising suitable field development strategies at an acceptable cost while maintaining satisfactory operational efficiency.
Are Your Geoscience Applications Maintaining the Integrity of the Geospatial Data?
Authors: Barrs Barry , Davis Jonathan , Latef M Zukhairi , Michell Mark , Shostak Brian , Stigant Jonathan 
Published: February 2011

Abstract:
The paper presents the results of a Joint Industry Project (JIP) to explore the integrity of the management of geospatial data in geoscience software applications (GIGS – Geospatial Integrity of Geoscience Software). The International Association of Oil and Gas Producers (OGP), Survey and Positioning (S&P) Committee administered the project; the members included 13 international O&G operating companies. The paper will be of interest and applicable to geoscience software architects and developers, geoscience software users, geoscientists, data managers and reservoir engineers and their respective asset and management teams. The JIP was formed to investigate the difficulties, experienced by both designers and users of geoscience software, of retaining the integrity of coordinate data when being processed, manipulated and interpreted in geoscience applications. The geoscience applications are being used to develop an understanding of sub-surface features from geophysical, geological, well log and other ancillary supporting data that have been loaded into the application. Clearly such information will lead to the placement of rigs to drill wells. The placement and subsequent management of these wells and the associated reservoirs are highly dependent on an accurate understanding and mapping of the data. This dependency is the primary motivation and driver for this JIP. The results of the JIP work are presented in the form of a new OGP guideline. The guideline contains geospatial requirements and recommendations with two associated annexes, providing a ‘roadmap’ to evaluate or review a given G&G application (annex 1), and a testing regime with an associated test dataset (annex2) to allow for such a review to be undertaken. An introduction, brief history, business case, and some examples of the guideline products, are included; these are to assist the reader in understanding the scope, the framework, the context and the potential impact of the work.
Low Salinity Waterflooding and Mineral Dissolution
Authors: Pu H. , Xie X. , Yin P. , Morrow N. R. 
Published: February 2011

Abstract
Numerous laboratory studies have shown that water composition can substantially affect oil recovery by waterflooding. Investigation of increased oil recovery by injection of low salinity water such as coalbed methane production water has been extended to reservoir cores from the Tensleep, Minnelusa and Phosphoria formations in Wyoming. The Tensleep and Minnelusa formations are eolean sandstones of comparable depositional environment that contain interstitial anhydrite, dolomite and occasional calcite cements. The Phosphoria dolomite has pin-point to coarse vuggy pores lined by sparry dolomite crystals and also features patches of anhydrite. All the cores taken from pay zones showed increased oil recovery ranging from 5 to 8% original oil in place through injection of low salinity water. Increase in sulfate ion content of the effluent brine confirmed the dissolution of anhydrite, for all three rock types. Proposed mechanisms of recovery by low salinity flooding of sandstones which are tied to the presence of clay cannot apply because none of these rocks have significant clay content. In addition to effluent composition, dissolution of anhydrite cement within Tensleep sandstone was previously demonstrated through pore level micro X-ray CT imaging. Further evidence of the role of anhydrite dissolution was provided by the recovery behavior of Tensleep cores taken from the water-saturated zones of an oil reservoir. Anhydrite cement was sparse and visible in occluded regions of pore space but not in regions that were clearly permeable. For these cores, there was no additional oil recovery when the injected brine was switched to low salinity water. The release of dolomite crystals and other fine embedded minerals which is likely associated with dissolution of anhydrite, may be a factor in the observed response to low salinity waterflooding. The movement of cement components is a possible contributing factor in the wide variety of observed relationships between pressure drop and oil recovery. For example, significant variation of relative permeability to brine at constant saturation is often observed.
Integration of 3D Seismic and Reservoir Simulation for Remaining Oil Exploitation in a Heavy Oil Field: A Case Study
Authors: Ling Yun , Huang Xuri , Guo Xiangyu , Cai Yintao 
Published: February 2011

Abstract
Based on a full azimuth 3D seismic (cell size 6.25m × 6.25m and coverage area 14 km2) and reservoir simulation on one well group (40 vertical wells and 5 horizontal wells in an area of 600m × 375m), integrated research on Steam Assisted Gravity Drainage (SAGD) production is carried out in an oilfield in Northeast China. The research indicated that the configuration of steam chambers caused by steam injection could be delineated from the high precision 3D seismic results, and it is more accurate than the reservoir simulation model in the local variation description of the chambers (the accuracy of the simulation model is influenced by density, porosity and permeability data). But with only seismic, it is difficult to differentiate the influence of geological sedimentation or small-size fracture from the steam chambers, and further predict the distribution of the remaining oil. By integrating the 3D seismic with a reservoir simulation model (thus forming a 3.5 D seismic method), we can predict the remaining oil. This approach is free from many technical difficulties facing time-lapse applications such as no baseline survey and non-repeatable noise.
Accelerating Progress Toward Achieving Digital Oilfield Workflow Efficiencies
Authors: Crawford Mark L. , Morneau Richard A. 
Published: February 2011

Abstract
The Upstream Oil and Gas Industry is working toward asset optimization through various Digital Oil Field of the Future (DOFF) programs. Significant progress has been made over the past few years, but the mission is not complete. The industry is still faced with challenges that inhibit system interoperability and in turn reduce workflow efficiencies. When one considers the software and data integration requirements to achieve the vision of the digital oilfield, one has to wonder if the Upstream Oil and Gas Industry will be able to maintain DOFF progress or if our advancements toward the digital oilfield may begin to plateau before we reach our objective. This paper considers the question "What are the key considerations to achieve the workflow efficiencies envisioned for the digital oilfield and how can we accelerate this process?" The authors probe the answer to this question by reviewing various IT-related standards activities, how they might improve workflow efficiencies, and the need for better coordination across standards development. The discussion will illustrate why the Upstream Oil and Gas Industry struggles with software and data integration. In conclusion, the authors will present thoughts around a path forward which they believe will help realize the industry's aspirations for the digital oilfield.