bluuebunny/crossref_metadata_2025_split huggingface dataset:
Enhanced Gas Recovery (EGR) with Carbon Dioxide Sequestration: A Simulation Study of Effects of Injection Strategy and Operational Parameters
Authors: Jikich Sinisha A. , Smith Duane H. , Sams W. Neal , Bromhal Grant S. 
Published: December 2007

Abstract
Injection of carbon dioxide into a natural gas reservoir is a promising technology for reducing anthropogenic gas emissions and increasing ultimate recovery of natural gas. Computer simulation is an important, inexpensive tool for designing pilot projects and predicting optimal tradeoffs between maximum methane production and maximum sequestration.
To investigate the amount of carbon dioxide sequestered and the effect of carbon dioxide injection on gas recovery, different injection strategies were used for a thin, shaly sandstone reservoir situated in Northern West Virginia. Two injection scenarios were studied: (1) simultaneous CO2 injection and methane recovery from the very beginning of the project, and (2) primary production of natural gas to the economic limit, followed by injection of carbon dioxide for secondary gas recovery. Horizontal injectors were used to increase injectivity. A 160-acre inverted 5-spot well pattern was studied for a pilot test.
The simulation results show that the highest methane recovery was obtained when the reservoir was produced under primary recovery until the economic limit, followed by CO2 injection. The maximum amount of incremental gas recovery was less than 10% of the original gas in place (OGIP). Lower recovery factors for methane were obtained in the case when CO2 injection was injected early. However, the early CO2 injection accelerated methane recovery and improved CO2 retention in the reservoir. The simulations also showed that there was an optimum length for the horizontal injectors to sequester the maximum amount of CO2.
By varying operational parameters such as time of primary production, injector length, injection pressure, injection timing, and production well pressure we can evaluate different production schemes to determine an optimum recovery of methane vs. CO2 sequestration. The findings of this study can be useful for finding tradeoffs between methane production and CO2 sequestration.
Decision and Risk Analysis Tools for the Oil and Gas Industry
Authors: Virine Lev , Rapley Lisa 
Published: December 2007

Abstract
The concept of decision and risk analysis for economic and engineering applications has become widely accepted in the petroleum industry. However, the actual use of decision and risk analysis tools remains limited, due mostly to complexity of these tools. Moreover, the professional use of these tools requires advanced knowledge of decision and risk analysis theory. The solution is to integrate decision and risk analysis tools into petroleum economic and engineering applications using developer&#39;s kits or toolsets. Advanced visualization techniques should be applied to provide the visual aids to input data with uncertainties and simplify the analysis of the results.
Surfactant Dewatering of Production and Gas Storage Wells
Authors: Ramachandran Sunder , Bigler John , Orta David 
Published: December 2007

Abstract
Surfactant dewatering of gas wells is a method best used in an operating envelope determined by existing gas flow rates, well bore inner diameters, pressures and temperatures. Baker Petrolite has designed a computer model to determine this operating envelope. The methodology can help delay costly mechanical dewatering methods yet still maintain production in the field. Case studies for both production and gas storage wells will be discussed.
The Importance in Developing a Surveillance Logging Quality Assurance and Quality Control Plan
Authors: Newman Mark A. 
Published: December 2007

Abstract
A quality assurance and quality control (QA/QC) plan is important to the success of a surveillance logging program. A QA/QC Plan for a surveillance logging program can provide adequate and accurate information in assessing the level of pipe defects reported from casing inspection logs and can be used to record possible trends regarding individual casing inspection tools1. Measurements taken from pulled well casing can be used to enhance the analysis of general corrosion in areas of large-diameter pits. Over time the accuracy in estimating depth of penetration in large-diameter corrosion pits can be improved.
Characterization of a Heterogeneous Reservoir in West Virginia
Authors: Aminian K. , Ameri S. , Bilgesu H. I. , Alla V. , Mustafa R. 
Published: December 2007

Abstract
The production performance of a reservoir is invariably influenced by the degree of heterogeneity present. Therefore, production performance of a heterogeneous reservoir cannot be realistically predicted without accurate reservoir characterization. In this study, a systematic and synergistic approach has been employed to integrate and interpret various geological and engineering data that are obtained at different scales to characterize a complex oil reservoir in West Virginia. The lack of detailed data significantly hampered the reservoir characterization efforts. However, innovative approaches that combined statistical and artificial intelligence techniques were successfully developed and utilized to predict the missing information. These approaches help reconcile stratigraphy, structural, and petrographic data with well log data, core analysis, and production data. The results were utilized to develop a model of the reservoir and to identify the flow units. The attributes of the flow units were quantified from well log data with help of Artificial Neural Networks (ANN). An innovative approach for training and testing of the ANN was developed which provided consistent and reliable predictions. Primary and secondary production data have been utilized to evaluate and modify the model. The flow unit model substantially improved the simulation of the secondary recovery performance. The simulation results confirmed the presence of heterogeneities which have had profound impact on the performance of the reservoir. The methodology presented in this paper can serve as a guideline for the characterization of reservoirs with limited data.
The Colfax Field Rose Run: A Reservoir Study
Authors: Freeman D. C. , Blomberg J. R. , Tardivo J. J. , Knobloch T. S. , James J. J. 
Published: December 2007

Abstract
A reservoir study was undertaken to evaluate methods for depletion of the Rose Run formation located in the Colfax Field, Fairfield County, Ohio. The original oil-in-place and the drainage area affected by the existing wells were determined. Per well drainage areas ranged from 0.5-22.3 acres, all significantly less than the state-prescribed 40-acre spacing for wells producing from depths greater than 4000 ft. Depletion from existing wells, new drills, a horizontal well, and waterflooding was subsequently examined, primarily through the use of black oil reservoir simulation.
Comparing Fracture Simulation Design to Radioactive Tracer Field Results: A Case History
Authors: Silber Richard , Martin Jason , Willis Stan , Kozera Greg 
Published: December 2007

Abstract
This paper highlights the value of post-fracture tracer analysis as an evaluation tool to aid in fracture design. A fracture design can be evaluated and compared to actual field results. When the results of this fracture design analysis are then compared to tracer analysis and to predicted and actual deliverability, fracture design can be improved and optimized. To verify this procedure, five wells were chosen for a case study.
The chosen gas storage reservoir had two active pay zones separated by 14-30 ft. Radioactive tracers were run in the treatments of five gas storage wells. Wells were then logged to determine the location of the tracers and determine whether both zones were effectively stimulated. In addition to determining whether zones were effectively stimulated, determining fracture height and comparing measured to the design fracture height was possible.
All of the wells were flow tested before stimulation, and potential deliverability increase was predicted. Post-stimulation flow potential was estimated by the choke flowback results and compared to predicted results. (Multi-point flow tests will be conducted after one year of storage activity to determine actual results.) Flowback results indicate good correlation between fracture design predictions and actual field results.
Development of a Correlation for Estimating Gelation in Porous Media Using Bottle Test Measurements
Authors: Awang Mariyamni , Seng Goh Meng 
Published: December 2007

Abstract
The bottle test method that is currently used to estimate gelation only provides a qualitative description and also does not necessarily reflect what happens in a porous media. This paper aims to show a relationship between the permeability of a porous medium that has been injected with a pre gel polymer and the gelling state given by a bottle test. In this way a better estimation of the gel strength in the reservoir can be made.
EOR: Past, Present and What the Next 25 Years May Bring
Authors: Stosur George J. 
Published: December 2007

Abstract
The paper presents an analysis of worldwide EOR activities and trends for the mid-term future. The focus of the paper is on EOR production levels and the corresponding number of projects within each major EOR technology group: thermal, gas flooding, chemical and other methods.
Most EOR activities are in North America where the conventional oil production decline is now well established and EOR is one of a few remaining options for additional oil production. In the United States, the unfavorable economic climate of the late 1980’s caused the number of new EOR projects to decline rapidly, followed by the corresponding leveling of oil production and even a modest EOR production decline in 2002.
Thermal recovery continues to provide the largest, although it is declining fraction of EOR production. In the long-term, thermal recovery methods may play an increasingly important role in the recovery of the huge heavy oil and tar sands resources. Gas flooding continues to gain momentum and shows promise for further gains. Chemical flooding projects suffered from declining interest and negligible production rate. Fluid diversion via permeability modification control offers considerable near-term potential.
It is likely that EOR-produced oil in the United States has already reached its peak level and that it will increase above the current production rates only at substantially higher and stable oil prices. World’s EOR production peak is likely to occur 30–35 years after the onset of global oil production decline, or in mid 2060’s.
Application of Artificial Intelligence to Characterize Naturally Fractured Reservoirs
Authors: El Ouahed A. Kouider , Tiab Djebbar , Mazouzi Amine , Jokhio Sarfraz A. 
Published: December 2007

Abstract
In highly heterogeneous reservoirs classical characterization methods often fail to detect the location and orientation of the fractures. Recent applications of Artificial Intelligence to the area of reservoir characterization have made this challenge a possible practice. Such practices consist of seeking the complex relationship between the fracture index and some geological and geomechanical drivers (Facies, porosity, permeability, bed thickness, proximity to faults, slopes and curvatures of the structure) in order to obtain a fracture intensity map using Fuzzy Logic and Neural Network.
This paper shows the successful application of Artificial Intelligence tools such as Artificial Neural Network and Fuzzy Logic to characterize naturally fractured reservoirs. A 2D fracture intensity map and fracture network map in a large block from Hassi Messaoud field have been developed using Artificial Neural Network and Fuzzy Logic.
This was achieved by first building the geological model of the permeability, porosity and shale volume using stochastic conditional simulation. Then by applying some geomechanical concepts first and second structure directional derivatives, distance to the nearest fault, and bed thickness were calculated throughout the entire area of interest. Two methods were then used to select the appropriate fracture intensity index. In first method well performance was used as a fracture index. In the second method, which consists of a new proposed approach, a Fuzzy Inference System (FIS) was built. With such system static to dynamic data was coupled to reduce the uncertainty and resulted in a more reliable Fracture Index. The different geological and geomechanical drivers were ranked with the corresponding fracture index for both methods using a Fuzzy Ranking algorithm. Only much important data were selected to be mapped with the appropriate fracture index using a feed forward Back Propagation Neural Network (BPNN). The neural network was then used to obtain a fracture intensity maps throughout the entire area of interest. A mathematical model based on "the weighting method" was then applied to obtain fracture network maps, which resulted in a deep insight about the major fracture trends.
The obtained maps were compared in the end and the results show that the proposed approach is a feasible methodology to map the fracture network.
Estimation of Surface Tension for Two Immiscible Fluids Using Lattice-Gas Automata
Authors: Kristanto Dedy , Awang Mariyamni 
Published: December 2007

Abstract
Surface tension is one of the important properties in enhanced oil recovery, particularly for gas-liquid displacement in porous media and separation process. It acts to keep interfaces of two immiscible fluids smooth, where two or more curved interfaces create pressure differences. The estimation and measurement of surface tension currently are made by capillary rise such as the ring method and the pendant drop method. In this paper, the lattice-gas automata method is being explored to be used in estimating the surface tension between two immiscible fluids in a porous medium. The main idea of immiscible lattice-gas model in this paper was the introduction of two species of particles (red for gas and blue for oil) to represent two immiscible fluids. The great advantage of the model was that interfaces and the interfacial dynamics were generated spontaneously. The surface tension was estimated by the Laplace’s equation and ranged between 0.00585 –0.00603. In general, simulation results are in good quantitative estimation and this simulation also allow us to model liquid-liquid or gas-liquid interactions. The aim was to see the suitability of lattice-gas automata in representing two immiscible fluids of oil and gas.
How to Fracture More Than 30 Zones in a Well in One Day and Used in a Large Scale
Authors: Demin Wang , He Liu , Yan Wang , Gang Wang 
Published: December 2007

Abstract
This paper introduces a method to fracture more than 30 zones in a single well per day and also how to fracture low permeability zones when the impermeable barrier(s) to high permeability and high water cut zones are only about 0.5 m thick and not create channels in the cement sheathe.
The above methods are used in a large scale in Daqing Oil Field (about 1,000 wells per year since 1980). The results are quite good, cumulative incremental oil production by these fracturing methods is about 60 million tons; the fracturing costs per ton of incremental oil is about $ 6.
Massive Hydraulic Fracturing – A Case History in Western Siberia, Russia
Authors: Nor-Azlan N. , Sanchez A. I. , Diyashev I. R. 
Published: December 2007

AbstractHydraulic fracturing has been the choice for well stimulation in Russia to enhance production for quite some time now. It was not until recently the treatment design has increased in size and magnitude in order to heed the country’s aggressive production enhancement strategy to meet the local and international demand. The focus of this paper is to discuss the technical and operational applicability of Massive Hydraulic Fracturing (MHF) strategy to enhance production in the Russian oil fields. A case history of the first well that was treated with MHF is provided. The well reflects the large majority of Russian oil wells, especially in the Western Siberian region, which have tremendous potential to enhance production via this strategy. The well falls in the low to intermediate permeability category (less than 1 to 50 md), which can often be converted to be excellent high producing wells by effective hydraulic fracturing technology coupled with proper artificial lifting system. A comprehensive technical analysis of the well before and after the treatment is provided. This includes production analysis using decline and/or type curve analysis before and after treatment, formation evaluation, well performance analysis to estimate the incremental gain, and forecasting. The design and operational aspects of the hydraulic fracturing treatment is also discussed. The results were encouraging. The production increased by more than double after the hydraulic fracturing treatment with relatively low water cut to date. The well was able to flow naturally after the treatment for a few months before artificial lift is installed.
New Dynamic Kill Procedure for Off-Bottom Blowout Wells Considering Counter-Current Flow of Kill Fluid
Authors: Flores-Avila Fernando S. , Smith John Rogers , Bourgoyne Adam T. 
Published: December 2007

Abstract
The "Dynamic Kill" technique has been used to perform off-bottom kills of both, surface and underground blowouts. Usually these kills are designed under the assumption that no kill fluid falls below the injection depth into the upward flow of the formation fluid. If this conservative assumption indicates that the kill is possible to achieve, the operator can confidently proceed with the field operations. However in some cases, calculations under this assumption will indicate that the kill is not possible, discarding a valuable potential solution to the problem. Recently completed research on counter-current flow of kill fluid falling through formation fluid that is flowing upward is applied here to off-bottom blowout wells. This study presents a procedure for controlling off-bottom blowout wells. It relies on the accumulation of liquid kill fluid injected while the well continues to flow to increase bottom hole pressure and assist in killing the well. The method is based on: The critical velocity that prevents control fluid accumulation which can be predicted by a new adaptation of Turner's model of terminal velocity (based on the liquid droplet theory.) This new model considers the flow regime of the continuous phase when evaluating the drag coefficient and the angle of deviation from the vertical.The amount of liquid that flows countercurrent into and accumulates within the well, which can be predicted based on the concept of Zero Net Liquid Flow (ZNLF) holdup.
These two concepts are integrated in the dynamic kill procedure, which is based on system performance analysis to better predict the feasibility of an off-bottom dynamic kill. These concepts were validated with full-scale experiments in a 2787-foot deep research well.
Planning the Well Construction Process for the use of Solid Expandable Casing
Authors: DeMong Karl , Rivenbark Mark 
Published: December 2007

Abstract
In the past, solid expandable casing technology has often been successfully used as a contingency measure to minimize the loss of hole size while dealing with drilling problems. Other applications, such as overall reduction of casing string sizes and numbers, sidetrack applications, and production conformance applications have been slower to attract interest, even though they are all technically viable and economic.
This paper will investigate the process for successfully integrating solid expandable tubulars into all aspects of the well construction program. Preparing the hole section for the installation of the solid expandables will be discussed. Drilling, completion, and production operations through expanded tubulars will also be reviewed.
The process of planning solid expandable projects from conception through well design will be investigated, focusing specifically on the ancillary technologies in the drilling, completion, and production phases. When all aspects of the well construction are optimized, the greatest economic value of solid expandables is achieved at the minimum operational risk.
Underbalanced Drilling For Production Enhancement in the Rasau Oil Field, Brunei
Authors: Sarssam Mark , Peterson Russell , Ward Mike , Elliott Dave , McMillan Scott 
Published: December 2007

Abstract
Underbalanced drilling (UBD) technology has been gaining in popularity around the world because of its capability to reduce or eliminate formation damage, to increase production rates, and in some cases, increase the volume of recoverable reserves. The technology is applicable to fields where formation damage is a concern or where problems such as severe fluid loss, differential sticking, steering problems or slow drilling rates are encountered with conventional drilling.
With underbalanced drilling, the formation pressure is greater than the hydrostatic pressure, allowing hydrocarbons to flow into the wellbore during drilling. This prevents potentially damaging drilling fluids and drilled fines from penetrating the producing formation.
In previous experiences in the field using traditional drilling methods, considerable formation damage had been experienced, and although UBD had never been attempted in the area before, Brunei Shell Petroleum and its government partner decided to use this technology in a three-well trial in the Rasau field, located onshore in Kuala Belait, Brunei.
Of the three wells attempted during this UBD trial one well could not be drilled due to catastrophic borehole collapse. The other two wells were successfully drilled to depth using UBD techniques; however, multiple hole volumes of solids were produced during drilling and production testing, indicating borehole stability problems.
Production rates observed after drilling to TD and prior to running completions indicated zero formation impairment, with well productivity exceeding expectation; however, during the completion phase, mechanical problems occurred, and post completion well tests indicated productivity reductions of 60 to 70% compared with the pre-completion tests. This paper discusses the planning, drilling, results, highlights, and lowlights from this UBD trial, along with learnings and recommendations for future application of the technology. The execution of the program led to a sharp learning curve, and the development of recommendations that can be applied to future operations in this field. These primarily relate to well (construction) design, drilling procedures, equipment design, rig-up and rig-down optimization between wells, and completion design.