bluuebunny/crossref_metadata_2025_split huggingface dataset:
Field Experiences in Application of a Novel Relative Permeability Modifier Gel in North Sea Operations
Authors: Wylde J. J. , Williams G. D. , Shields C. 
Published: December 2007

AbstractProposalOver a dozen successive selective water shut off treatments (SWSO) have been performed on an individual North Sea field. The target wells were vertical, cased, perforated producers in a mature, high scale potential asset in the UKCS. Reservoir temperatures were in excess of 121°C and permeability ranged from 100 – 1000 mD. Mention is also given to several other treatments performed in this mature field on wells with water rates up to 16,500 bwpd.Treatments were generally bullheaded as part of a scale inhibitor squeeze intervention, being contained in the final portion of the over flush. Results were all positive and in one case reduced water production by up to 60%. Furthermore, oil production was stimulated by up to 250%. The non-hazardous, low concentration chemical treatments were developed for pumping from the surface to reduce water production without affecting hydrocarbon production. It is more generally applicable than previous SWSO systems as it can be applied from ambient temperatures up to 130°C and 20mD – 16 D.This paper details the treatment design and pre-qualification experiments to a variety of field applications of a novel relative permeability modifier gel. Details are given regarding the pumping schedule, treatment well test data, and lessons learnt from the operations.
Methodology for Miscible Gas Injection EOR Screening
Authors: Teletzke G. F. , Patel P. D. , Chen A. L. 
Published: December 2007

AbstractMiscible gas injection is the most widely applied light oil enhanced oil recovery (EOR) process. A methodology, based on well-established physical principles, has been developed for estimating the conditions under which gas will be miscible with oil. The methodology enables rapid screening of a range of potential gas injectants (such as CO2, enriched hydrocarbon gas, N2, or H2S) through the use of readily available gas and oil properties. The methodology has been applied to numerous reservoirs worldwide. An overview of the methodology is provided along with an illustration of its application to screening of gas injection EOR for the Malay Basin.The methodology makes use of a correlation1 that can be used to rapidly estimate miscible or near-miscible residual oil saturation, Sorm, minimum miscibility pressure (MMP), or minimum miscibility enrichment (MME) for a wide range of injected gases, crude oils, temperature and pressure conditions. The correlation is based on representation of the physical and chemical properties of the crude oil and injected gas through Hildebrand solubility parameters.Thirty-four offshore reservoirs operated by either ExxonMobil Exploration and Production Malaysia Inc. (EMEPMI) or production sharing contract (PSC) partners were screened for gas injection EOR. Potential injection gases included pure CO2, CO2 diluted with methane, field separator gas, CO2 enriched with LPG, and separator gas enriched with LPG. A spreadsheet was created to facilitate calculation of MMP or MME using the solubility parameter correlation for a large number of reservoirs and potential injection gases. The correlation was useful for ranking reservoirs and potential injectants with respect to gas injection EOR potential and identifying which reservoirs to carry forward for in-depth laboratory and simulation evaluation.In general, the predictions of the correlation compare reasonably with the more costly experimental data obtained in subsequent detailed evaluation.
Optimizing the Blowdown of Wizard Lake
Authors: Cook P. G. 
Published: December 2007

Abstract
The Wizard Lake D3 A pool went to blowdown in 2003, after achieving 86 % oil recovery from a vertical hydrocarbon miscible flood scheme. This paper describes some of the optimizations leading up to blowdown to increase gas sales and, in the initial stages of blowdown, to increase oil sales. A novel enhanced gas recovery scheme is also discussed, in which aquifer influx is diverted to another depleted pool through a horizontal well.
Solids Control and Waste Management for SAGD
Authors: Richards M. , Monkman B. , Comeau P. , Grant J. 
Published: December 2007

Abstract
The need to drill wells quickly and efficiently has challenged traditional thinking for solids control equipment, disposal services and fluids management practices in Steam Assisted Gravity Drainage (SAGD) drilling operations. Effective control of drilled solids and proper waste treatment are combined into an integrated fluids management program to address the challenges. Simultaneously, proper management of drilling wastes to meet more stringent environmental compliance must be addressed and coordinated amongst all parties.
Current practices address these needs, but have evolved in tandem with other aspects of drilling operations to suit the particulars of SAGD operations. Today's practices will also evolve as technologies advance; the evaluative philosophy and proper project management however remain an integral part of the process itself, and naturally foster future improvements which in-turn reduce risk both financially and environmentally.
High Mobility Ratio Water Flood Performance Prediction: Challenges and New Insights
Authors: Kumar M. , Hoang V. , Satik C. , Rojas D. H. 
Published: December 2007

Abstract
This paper presents results of a comprehensive study to improve our understanding of High Mobility Ratio Water Flood (HMRWF) and to improve its performance prediction. Published data on heavy oil water injection field projects are limited. Several successful HMRWF projects have been reported, and they show significant oil recovery at high water cut. However, the range of reported recovery is large – waterflood recoveries of ~ 1-2% to 20% OOIP have been reported for similar reservoirs. Higher viscosities result in lower recovery
Mechanistic study using fine-scale simulations show that viscosity (or mobility) ratio primarily controls oil recovery response, and that the recovery is lower at higher viscosity ratios. Further, viscous fingers dominate high viscosity ratio floods, and mobile water can significantly reduce recovery. Field-scale simulation results indicate that heterogeneity plays a more important role for a HMRWF (than conventional waterfloods). The amount of primary production prior to the start of the waterflood has a larger effect on incremental oil recovery for high mobility ratio floods. Further, highly-correlated, thin, thief zones reduce recovery of HMRWF more severely, and rock wettability (relative permeabilties) strongly influences oil recovery. These results indicate that accurate viscosity and relative permeability measurements are essential for a reliable performance prediction.
New Developments in Streamflood Modeling
Authors: Kumar M. , Satik C. , Hoang V. 
Published: December 2007

Abstract
Using recent results from fine-scale, multi-pattern, geostatistical models of the Kern River field, California, this paper reviews key issues related to steamflood modeling and shows that fine-grid models depict the near-vertical steam override, and corroborates that heavy oil steamflooding is not a displacement process; rather the oil drains by gravity. Further, models with unconfined boundaries result in steam zone pressures similar to those observed in field. Including the common operating practice of cyclic steaming of producers at early time reduces pressures and accelerates steam breakthrough time and recovery.
Furthermore, pattern element and single sand models used in many previous studies are not sufficient to explain observed field performance, and that larger, heterogeneous model give more realistic recovery predictions. Discontinuous shales allow significant drainage to occur from the upper to the lower sands. Consequently, the upper zones may contain less reserve than expected and the lower zones can give apparent high recovery. Use of parallel models showed significant speed up over serial models allowing significantly larger models to be run in a reasonable time. Apparent higher speed up is gained for larger models.
The paper demonstrates that the current improvements make larger-scale modeling of steamflood projects viable compared with what was possible earlier and that a realistic forecast of steamflood performance is attained when the necessary details are included in the model.
Case History: First Commercial Illinois Coalbed Methane Project Commences through a Structured Resource Evaluation Plan
Authors: Rodvelt G. D. , Oestreich R. G. 
Published: December 2007

Abstract
The Illinois Basin has an estimated 21 Tcf of natural gas trapped in the coal seams that cover Illinois and Indiana. A Saline County, Illinois coalbed methane (CBM) project has been selling gas into pipelines. The authors describe the evaluation plan used to set up a pilot project and proceed into field development.
A step-wise program of gathering reservoir data preceded a successful pilot program where gas-content information, thickness maps, and adsorption isotherms were acquired and integrated into a Davis and Dekoven drilling program. Gas producibility was established from a five-spot pilot (five wells drilled in a field to help operators evaluate the CBM commercial potential of the field) leading to a 30-well development program in 2004. Well information presented includes spacing, orientation, reservoir parameters, and completion designs. The description of a remote monitoring system that reduces labor costs and provides real-time data via the Internet is also provided. Future expansion plans include additional testing and zonal completions.
Post-Yield Material Characterization for Thermal Well Design
Authors: Kaiser T. 
Published: December 2007

Abstract
Conventional material specifications and test methodologies were developed to support load-based designs in which inelastic deformations are relatively small and yield strength is the primary material factor governing design. However, in strain-based designs where substantial portions of the structure soften under post-yield deformation, more detailed characterization of the post-yield material behavior is required. This paper presents a framework for describing the post-yield properties of metals, including strain-rate dependence of yield strength, a testing methodology for measuring post-yield strength in terms of strain and strain rate, and an analytical basis for extrapolating measured properties to static conditions for strain-based design and quality assurance.
3D Geomodelling and Flow Simulation of the Late Devonian Bakken Formation in South-Central Saskatchewan - Case Study: Smiley Buffalo Heavy Oil Waterflood
Authors: Mohr R. , Estrada C. A. , Norrena K. 
Published: December 2007

Abstract
A sound geological model, a consistent geocellular model, and flow simulation are all critical components to successful optimization of a heavy oil waterflood project. Despite the availability of a sound geologic model, high quality seismic and abundant core, log, and production data, optimization of the waterflood project at the Smiley Buffalo field in south-central Saskatchewan held many challenges
The primary reservoir at Smiley is the middle Bakken sandstone which was deposited as offshore sand ridges in late Devonian to early Mississippian time. The reservoir structure has been subjected to post-depositional solutioning of the underlying Torquay Formation and karstification which causes reservoir breaks, fracture networks, and irregularities in the saturation functions. These features have important effects on reservoir performance. The geologic model and seismic information were used to construct a consistent structural model. A facies classification model was built with fuzzy logic which used the core and log data as well as the geologic model. Sequential indicator simulation was used to populate the structural model with facies information, and sequential Gaussian simulation was used to populate the petrophysical properties. Representative models were selected for upscaling and flow simulation and subsequent well location selection.
Evaluation of the Potential for Reduction in Well Spacing of the Bakken Sand Pool, Court Field
Authors: Majcher M. B. , Estrada C. A. , Archer J. C. 
Published: December 2007

Abstract
In West Central Saskatchewan the Mississippian/Devonian middle Bakken Formation was deposited as NE-SW trending sand ridges, capable of producing heavy oil. In the Court field, the middle Bakken sand pool has been operated as a heavy oil waterflood for over 15 years with significant success. A review of an earlier field simulation was conducted, an updated model generated, and the potential for reduction in well spacing has been identified.
The lateral continuity of the sand ridge is variable due to post-depositional sinkholes. This structural complexity was mapped based on 3D seismic and well-logs and incorporated into the model. There were also stratigraphic disparities to take into account as discontinuous interbedded siltstones are potential flow barriers that create anisotropy in the permeability. Accordingly, grid orientation was modified to align axially with the main sand ridge permeability trends. Reservoir properties were re-assessed through correlation of cores, well-logs, porosity and permeability maps. Improved resolution was obtained with an increase in the amount of grid blocks used to account for the effect of grid orientation and numerical dispersion on the saturation distribution. A thorough analysis of pressure history, production/injection rates, waterflood performance by pattern interference, and dye injection tests were used to control the history matching process. The simulation model was then used to evaluate the downspacing potential and waterflood optimization of the middle Bakken reservoir.
Geostatistical Modeling Integral to Effective Design and Evaluation of SAGD Processes of an Athabasca Oil-Sands Reservoir: A Case Study
Authors: Robinson B. , Kenny J. , Hdez I. L. Hernandez , Bernal A. , Chelak R. 
Published: December 2007

Abstract
The design and implementation of a successful thermal recovery project starts with a representative static geological model. SAGD operating strategies of the steam chamber for optimum economical oil recovery with minimum SOR are largely controlled by the target reservoir geological and pressure environment.
This paper describes how geostatistical modeling techniques were used to build a static reservoir model over a 32-section area of a Fort McMurray oil sand reservoir. The model was constructed by using Roxar's Irap RMS modeling software. Irap RMS provided a platform that facilitated geostatistical mapping of horizons and populating the petrophysical properties over a 3.46 million cell static geological model. This paper describes how the petrophysical logs and core data from 33 wells in the study area were integrated into a coherent geostatistically based geological model from which any number of equiprobable realizations of the geological environment may be drawn.
The large scale geological model was built so that the impact of regional variability of reservoir quality on SAGD process strategies could be evaluated, optimized and readily assessed by using dynamic simulation techniques and by extracting and appropriately upscaling portions of the static reservoir model. This modeling strategy also allows risk analysis of geological uncertainty at a given location on SAGD performance to be evaluated by conducting and analyzing multiple dynamic simulation runs generated from equiprobable realizations of the static geological model. The use of geostatistical techniques to assess data quality and impact of geological uncertainty on the geological description are reviewed. The impact of this uncertainty on quantification of bitumen in place and its impact on establishing and prioritizing the placement of well pairs are also presented.
A review of the geology and the workflow followed by integrating petrophysics, core data, mapping of horizons, and rock types are discussed. The extraction and upscaling process used to create the dynamic simulation is described. The workflow strategy that was adopted allowed the definition and evaluation of SAGD operating strategies across the field to be evaluated concurrently and quickly with representative dynamic simulation models of a reasonable size.
Opportunity Generation in a 96% Depleted Billion Barrel Oilfield
Authors: Burnett Philip J. 
Published: December 2007

Abstract
In 2000, a multi-disciplinary technical team was formed to assess the potential remaining in a 96% depleted 1.3 billion BO recoverable oilfield complex (the Central Fields) in Bass Strait, Australia.
The first step was an extensive ‘data-mining’ exercise of the ~125 wells with ~500 completions in numerous reservoir units and 35 years of production history. This was followed by a period of geoscience/engineering collaborative analysis. A detailed field-wide reservoir correlation was integrated with production performance history and well-to-well interactions. These efforts resulted in the identification of an inventory of opportunities ranging from low-cost work-over operations to new drill-well candidates. A series of work-over operations performed from 2001 to 2004 yielded initial individual oil production rates of 1 thousand to 7 thousand BOPD and a total incremental reserve capture of over 10 million BO. In 2003, a two-well drilling program added in excess of 3 million BO recoverable with an initial production buildup of over 6 thousand BOPD
While relatively sophisticated techniques such as sequence stratigraphy and well performance modeling were important, these successful programs were primarily the result of rigorous data analysis and integration of geoscience and engineering workflows and were achieved with minimal advanced technology. Ongoing collaboration between geoscience and engineering will leverage off the documented results and incorporate future performance data to yield further insights and additional work-over and drill-well opportunities.
Oily-Water Treatment Schemes For Steam Generation in SAGD Heavy-Oil Developments
Authors: Pedenaud P. , Michaud P. , Goulay C. 
Published: December 2007

Abstract
Production of extra heavy oil or bitumen by means of SAGD (Steam Assisted Gravity Drainage) requires the generation and injection into the reservoir of a great quantity of steam. A corresponding quantity of hot water is then produced along with the mobilised oil. Bearing in mind existing and future environmental regulations, it is likely that partial or even total recycling of this produced water back into steam will become mandatory.
The complexity of the water treatment scheme required depends on the water characteristics, the steam boiler specification (OTSG or conventional 100% steam boiler) and whether or not waste water disposal is completely eliminated (zero reject) or not. SAGD developments have some specific water treatment issues which need to be addressed, for example the high silica content of the produced water. This paper will present different conceptual designs for a 300 000 bwpd water treatment plant. The different schemes discussed include an OTSG boiler, a conventional boiler and the zero disposal option. The various options available for process equipment will be presented, together with two different salinities of produced water and their impact on process design. Included will be an evaluation of capital cost and operating costs elements.
The Challenge Facing Multiphase Metering in Oil-Sands Thermal Developments
Authors: Arendo V. , Goulay C. , Stobie G. , Wall T. , Couput J. P. 
Published: December 2007

Abstract
Multiphase metering flow meters (MPFM) are being accepted more and more in oil and gas developments, replacing test separators, particularly on fields with large well networks. This is the case with Steam Assisted Gravity Drainage (SAGD) oil sands developments requiring large capital investment that need accurate production and reservoir data and have difficult processing techniques. This data includes: Real time measurement: good reservoir and steam chamber monitoring and steam injection versus oil production surveys.Cost reduction: steam oil ratio (SOR) optimisation, due to the economic and environmental cost of steam.Asset integrity: mitigation of the risk of steam breakthrough in oil producer wells.
The flow meters have to be sized for either viscous liquids (water in oil emulsions) or less viscous, but very hot liquids (oil in water emulsions) and to differentiate between gas and steam, or be able to meter the gas and assess the steam loading. In SAGD developments the water content determination is essential and the meters have to include qualified systems for both high temperature and high water cut measurements.
This paper outlines the business needs for MPFMs in SAGD and discusses the current difficulties with qualification, test loops, field trials and eventually, the perceived operational issues. The challenges facing multiphase metering in SAGD developments are as difficult as the industry faced when applying classical multiphase metering techniques several years ago. In order that these challenges are overcome it will be necessary for vendors and operators to develop and test the new technologies jointly. This will require that vendors dedicate sufficient effort in MPFM R&D and that operators participate in these developments, in JlP's and host field trials.
The Impact of Upgrader Location on Steam Generation
Authors: Michaud P. , Goulay C. , Sabbag J. N. , Thiery G. , Kehoe R. 
Published: December 2007

Abstract
Extra heavy oil (or bitumen) production through Steam Assisted Gravity Drainage (SAGD) requires large amounts of steam, which are classically produced by natural gas combustion using Once Through Steam Generators (OTSG). Steam production is a major SAGD operating cost, which has increased significantly with current high natural gas prices.
In order to reduce these costs or to mitigate for the risk of insufficient natural gas supply, several alternatives to natural gas for steam generation have been investigated, such as bitumen itself, coal, or ultra-low API "bottom of the barrel" residual by-products resulting from bitumen upgrading.
Two methods of utilizing these by-products are available: direct combustion and gasification. The advantage of gasification is that it produces desulphurized syngas that can be substituted for natural gas in conventional OTSG boilers. Gasification of asphaltenes to a synthetic gas (syngas) can be achieved by different technologies: partial oxidation (POX) technologies being the most widely known.
Whether or not an upgrader is present at the SAGD field site may dictate the type of fuel burnt or gasified and also the type of any gasification unit.
This paper describes the main conclusions of a study into the decision drivers for each steam generation alternative. A technical and economic model has been developed, which screens various extra heavy oil development scenarios.
This model has allowed an informed evaluation of the impact of upgrader location on steam generation cost and potential environmental impact, by considering CO2 emissions, possible upgrading by-products and their disposal and valorization for each scenario.