AndreaBozzo/ceres-open-data-index huggingface dataset:
OPTICAL FIBER SENSOR TECHNOLOGIES FOR EFFICIENT AND ECONOMICAL OIL RECOVERY

This report summarizes technical progress over the fourth year of the ''Optical Fiber Sensor Technologies for Efficient and Economical Oil Recovery''program, funded by the Federal Energy Technology Center of the U.S. Department of Energy, and performed by the Center for Photonics Technology of the Bradley Department of Electrical and Computer Engineering at Virginia Tech. During the reporting period, research efforts under the program were focused on the development and evaluation of the fiber optic flow sensor system, and field testing in Tulsa, OK and the second field test of the pressure and temperature sensors in Coalinga, CA. The feasibility of a self-compensating fiber optic flow sensor based on a cantilever beam and interferometer for real-time flow rate measurements in the fluid filled pipes of oil field was clearly demonstrated. In addition, field testing of the pressure and temperature sensors deployed downhole continued. These accomplishments are summarized here: (1) Theoretical analysis and simulations were performed to ensure performance of the design. (2) The sensor fabrication and packaging techniques were investigated and improved. (3) Prototype flow sensors were fabricated based on the fabrication experience of hundreds of test sensors. (4) A lab-scale flow testing system was constructed and used for sensor evaluation. (5) Field-testing was performed in both the indoor and outdoor flow testing facility at the University of Tulsa, OK. (6) Testing of a multimode white light pressure and temperature sensor system continued at the oil site of Chevron/Texaco Company (Coalinga CA).

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Microdrill Initiative - Initial Market Evaluation

The U.S. Department of Energy (DOE) is launching a major research and development initiative to create a small, fast, inexpensive and environmentally friendly rig for drilling 5000 feet boreholes to investigate potential oil and gas reservoirs. DOE wishes to get input from petroleum industry operators, service companies and equipment suppliers on the operation and application of this coiled-tubing-based drilling unit. To that end, DOE has asked Spears & Associates, Inc. (SAI) to prepare a special state-of-the-market report and assist during a DOE-sponsored project-scoping workshop in Albuquerque near the end of April 2003. The scope of the project is four-fold: (1) Evaluate the history, status and future of demand for very small bore-hole drilling; (2) Measure the market for coiled tubing drilling and describe the state-of-the-art; (3) Identify companies and individuals who should have an interest in micro drilling and invite them to the DOE workshop; and (4) Participate in 3 concurrent workshop sessions, record and evaluate participant comments and report workshop conclusions.

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IMPROVED MISCIBLE NITROGEN FLOOD PERFORMANCE UTILIZING ADVANCED RESERVOIR CHARACTERIZATION AND HORIZONTAL LATERALS IN A CLASS I RESERVOIR - EAST BINGER (MARCHAND) UNIT

Progress on the East Binger Unit (EBU) project has slowed as difficulties have been encountered with obtaining satisfactory production from well EBU 37G-3H, the new horizontal well. Remedial operations have been conducted and stimulation operations were about to get under way at the end of the reporting period. International Reservoir Technologies, Inc. has made additional progress on the pilot area simulation model, reaching a point with the history match that we are awaiting more definitive production data from the horizontal well. Planning future development of the EBU hinges on evaluating the results of well EBU 37G-3H. Performance of this well must be understood in order to evaluate development scenarios involving horizontal wells and compare them with development scenarios involving vertical wells.

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IMPROVED MISCIBLE NITROGEN FLOOD PERFORMANCE UTILIZING ADVANCED RESERVOIR CHARACTERIZATION AND HORIZONTAL LATERALS IN A CLASS I RESERVOIR - EAST BINGER (MARCHAND) UNIT

The first horizontal well ever in the Marchand sandstone has been drilled. Although major difficulties arose with certain aspects of the drilling operation, a horizontal section of approximately 1300 was drilled. The section was left open hole as planned. The shales just above and between the Marchand sands appear to be very water-sensitive, requiring careful drilling practices. These shales were encountered in the middle part of the curve (45{sup o}-60{sup o}), which can be the most difficult part of a directional well to clean. Difficulties with these shales and cleaning this section led to a parted drill string, requiring a sidetrack. There were no major geologic ''surprises'', such as formation tops coming in much shallower or deeper than expected, or unexpected faults. Thin kaolinite beds were encountered in the horizontal section of the well. Previous descriptions of the mineralogy of this formation did not mention any kaolinite. The lateral extent of these beds is unknown. Completion of the well is under way. One additional injection profile was gathered during the quarter. Results are consistent with other recently profiles that show gas within the C Sand is overriding the oil and failing to sweep the deeper parts of the reservoir. International Reservoir Technologies, Inc. has completed the construction of the pilot area reservoir simulation model and the updating of historical production and injection data. They have begun fine-tuning the history match to better match production data and recently acquired pressure and profile data.

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IMPROVED MISCIBLE NITROGEN FLOOD PERFORMANCE UTILIZING ADVANCED RESERVOIR CHARACTERIZATION AND HORIZONTAL LATERALS IN A CLASS I RESERVOIR - EAST BINGER (MARCHAND) UNIT

Work associated with Budget Period 1 of the East Binger (Marchand) Unit project is nearing completion. A major aspect of this project is accurate modeling of the performance of horizontal wells. Well EBU 37-3H, the first horizontal well drilled in the unit, was drilled in the second quarter of 2001. After much difficulty establishing economic production from the well, the well was hydraulically fractured in November 2001. Post-treatment production has been very encouraging and is significantly better than a vertical well drilled in a similar setting. International Reservoir Technologies, Inc. has completed the final history match of the pilot area reservoir simulation model, including tuning to the performance of the horizontal well. The model's predicted reservoir pressure gradient between injection and production wells accurately matches observed data from the field, a significant improvement from prior model predictions. The model's predicted gas injection profiles now also more accurately match field data. Work has begun toward evaluating the optimum development scenario with the pilot model. Initially, four scenarios will be evaluated--two involving all horizontal infill wells, one involving all vertical infill wells, and one involving a combination of vertical and horizontal infill wells. The model cases for these scenarios have been defined, and construction of them is underway.

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IMPROVED MISCIBLE NITROGEN FLOOD PERFORMANCE UTILIZING ADVANCED RESERVOIR CHARACTERIZATION AND HORIZONTAL LATERALS IN A CLASS I RESERVOIR - EAST BINGER (MARCHAND) UNIT

Implementation of the work program of Budget Period 2 of the East Binger Unit (''EBU'') DOE Project continues. Significant advances with the reservoir simulation model have led to changes in the program. One planned horizontal well location, EBU 44-3H, has been eliminated from the program, and another, EBU 45-3H, has been deferred, and may be replaced by a vertical well or completely eliminated at a future date. A new horizontal well location, EBU 63-2H, has been added. EBU 74G-2, the one new injection well planned for the project, was completed and brought on production. It will be produced for a period of time before converting it to injection. Performance is exceeding expectations. Work also continued on projects aimed at increasing injection in the pilot area. EBU 65-1 was converted to injection service. The project to add compression and increase injection capacity at the nitrogen management facility is nearing completion. Additional producer-to-injector conversions will follow.

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FIELD DEMONSTRATION OF CARBON DIOXIDE MISCIBLE FLOODING IN THE LANSING-KANSAS CITY FORMATION, CENTRAL KANSAS

Progress is reported for the period from January 1, 2002 to March 31, 2002. Technical design and budget for a larger (60-acre, 24.3 ha) CO2 demonstration project are being reviewed by the US DOE for approval. While this review process is being conducted, work is proceeding on well testing to obtain reservoir properties and on the VIP reservoir simulation model to improve model prediction and better understand the controls that certain parameters exert on predicted performance. In addition, evaluation of the economics of commercial application in the surrounding area was performed. In a meeting on January 14, 2002 the possibility of staging the demonstration, starting with a 10-acre sub-pattern flood was raised and the decision made to investigate this plan in detail. The influence of carbon dioxide on oil properties and the influence of binary interaction parameters (BIP) used in the VIP simulator were investigated. VIP calculated swelling factors are in good agreement with published values up to 65% mole-fraction CO2. Swelling factor and saturated liquid density are relatively independent of the BIP over the range of BIPs used (0.08-0.15) up to 65% mole-fraction CO2. Assuming a CO2 EOR recovery rate projected as being most likely by current modeling, commercial scale CO2 flooding at $20/BO is possible in the leases in Hall-Gurney field. Relatively small floods (240-320 acres, 4-6 patterns) are economically viable at $20/BO in areas of very high primary and secondary productivity (&gt;14 MBO/net acre recovery). Leases with moderately high primary and secondary productivity (&gt; 10 MBO/net acre recovery) can be economic when combined with high productivity leases to form larger floods (&gt;640 acres, 9 or more patterns).

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Investigation of Efficiency Improvements During CO2 Injection in Hydraulically and Naturally Fractured Reservoirs

The objective of this project was to perform unique laboratory experiments with artificial fractured cores (AFCs) and X-ray CT to examine the physical mechanisms of bypassing in HFR and NFR that eventually result in less efficient CO2 flooding in heterogeneous or fracture-dominated reservoirs. This report provided results of the second semi-annual technical progress report that consists of three different topics.

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Economic Implementation and Optimization of Secondary Oil Recovery Process: St. Mary West Field, Lafayette County, Arkansas

The purpose of this study was to investigate the economic appropriateness of several enhanced oil recovery processes that are available to a small mature oil field located in southwest Arkansas and to implement the most economic efficient process evaluated. The State of Arkansas natural resource laws require that an oilfield is to be unitized before conducting a secondary recovery project. This requires all properties that can reasonably be determined to include the oil productive reservoir must be bound together as one common lease by a legal contract that must be approved to be fair and equitable to all property owners within the proposed unit area.

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New Acid Stimulation Treatment to Sustain Production - Los Angeles Downtown Oil Field

Hydrochloric acid stimulation was successfully used on several wells in the Los Angeles Downtown Field, in the past. The decline rates after stimulation were relatively high and generally within six months to a year, production rates have returned to their prestimulation rates. The wells in Los Angeles Downtown Field have strong scale producing tendencies and many wells are treated for scale control. Four wells were carefully selected that are representative of wells that had a tendency to form calcium carbonate scale and had shown substantial decline over the last few years.

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Water as a Reagent for Soil Remediation

SRI International conducted experiments in a two-year, two-phase process to develop and evaluate hydrothermal extraction technology, also known as hot water extraction (HWE) technology, for remediating petroleum-contaminated soils. The bench-scale demonstration of the process has shown great promise, and the implementation of this technology will revolutionize the conventional use of water in soil remediation technologies and provide a standalone technology for removal of both volatile and heavy components from contaminated soil.

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Application of Chemically Accelerated Biotreatment to Reduce Risk in Oil-Impacted Soils

Research was conducted in six major focus areas: (1) Evaluation of the process using 6 test soils with full chemical and physical characteristics to determine controlling factors for biodegradation and chemical oxidation; (2) Determination of the sequestration time on chemical treatment suspectability; (3) Risk factors, i.e. toxicity after chemical and biological treatment; (4) Impact of chemical treatment (Fenton's Reagent) on the agents of biodegradation; (5) Description of a new genus and its type species that degrades hydrocarbons; and (6) Intermediates generate from Fenton's reagent treatment of various polynuclear aromatic hydrocarbons.

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Application of Chemically Accelerated Biotreatment to Reduce Risk in Oil-Impacted Soils

Conducted research in the following major focus areas: (1) Development of mild extraction approaches to estimate bioavailable fraction of crude oil residues in contaminated soils; (2) Application of these methods to understand decreases in toxicity and increases in sequestration of hydrocarbons over time, as well as the influence of soil properties on these processes; (3) Measurements of the abilities of various bacteria (PAH-degraders and others more representative of typical soil bacteria) to withstand oxidative treatments (i.e. Fenton's reaction) which would occur in CBT; and (4) Experiments into the biochemical/genetic inducibility of PAH degradation by compounds formed by the chemical oxidation of PAH.

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Risk Reduction with a Fuzzy Expert Exploration Tool

A state-of-the-art exploration ''expert''tool, relying on a computerized database and computer maps generated by neural networks, was developed through the use of ''fuzzy''logic, a relatively new mathematical treatment of imprecise or non-explicit parameters and values. Oil prospecting risk can be reduced with the use of a properly developed and validated ''Fuzzy Expert Exploration (FEE) Tool.''This FEE Tool can be beneficial in many regions of the U.S. by enabling risk reduction in oil and gas prospecting as well as decreased prospecting and development costs.

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Compendium of Regulatory Requirements Governing Underground Injection of Drilling Wastes

This report provides a comprehensive compendium of the regulatory requirements governing the injection processes used for disposing of drilling wastes; in particular, for a process referred to in this report as slurry injection. The report consists of a narrative discussion of the regulatory requirements and practices for each of the oil- and gas-producing states, a table summarizing the types of injection processes authorized in each state, and an appendix that contains the text of many of the relevant state regulations and policies.

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Advanced Chemistry Basins Model

The objective of this project is to: (1) Develop a database of additional and better maturity indicators for paleo-heat flow calibration; (2) Develop maturation models capable of predicting the chemical composition of hydrocarbons produced by a specific kerogen as a function of maturity, heating rate, etc.; assemble a compositional kinetic database of representative kerogens; (3) Develop a 4 phase equation of state-flash model that can define the physical properties (viscosity, density, etc.) of the products of kerogen maturation, and phase transitions that occur along secondary migration pathways; (4) Build a conventional basin model and incorporate new maturity indicators and data bases in a user-friendly way; (5) Develop an algorithm which combines the volume change and viscosities of the compositional maturation model to predict the chemistry of the hydrocarbons that will be expelled from the kerogen to the secondary migration pathways; (6) Develop an algorithm that predicts the flow of hydrocarbons along secondary migration pathways, accounts for mixing of miscible hydrocarbon components along the pathway, and calculates the phase fractionation that will occur as the hydrocarbons move upward down the geothermal and fluid pressure gradients in the basin; and (7) Integrate the above components into a functional model implemented on a PC or low cost workstation.

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Development of Reservoir Characterization Techniques and Production Models for Exploiting Naturally Fractured Reservoirs

This research was directed toward developing a systematic reservoir characterization methodology which can be used by the petroleum industry to implement infill drilling programs and/or enhanced oil recovery projects in naturally fractured reservoir systems in an environmentally safe and cost effective manner. It was anticipated that the results of this research program will provide geoscientists and engineers with a systematic procedure for properly characterizing a fractured reservoir system and a reservoir/horizontal wellbore simulator model which can be used to select well locations and an effective EOR process to optimize the recovery of the oil and gas reserves from such complex reservoir systems.

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Fundamentals of Delayed Coking Joint Industry Project

The coking test facilities include three reactors (or cokers) and ten utilities. Experiments were conducted using the micro-coker, pilot-coker, and stirred-batch coker. Gas products were analyzed using an on-line gas chromatograph. Liquid properties were analyzed in-house using simulated distillation (HP 5880a), high temperature gas chromatography (6890a), detailed hydrocarbon analysis, and ASTM fractionation. Coke analyses as well as feedstock analyses and some additional liquid analyses (including elemental analyses) were done off-site.

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Quantitative Methods for Reservoir Characterization and Improved Recovery: Application to Heavy Oil Sands

Improved prediction of interwell reservoir heterogeneity was needed to increase productivity and to reduce recovery cost for California's heavy oil sands, which contain approximately 2.3 billion barrels of remaining reserves in the Temblor Formation and in other formations of the San Joaquin Valley. This investigation involved application of advanced analytical property-distribution methods conditioned to continuous outcrop control for improved reservoir characterization and simulation.

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Quantitative Methods for Reservoir Characterization and Improved Recovery: Application to Heavy Oil Sands

This project involved application of advanced analytical property-distribution methods conditioned to continuous outcrop control for improved reservoir characterization and simulation. The investigation was performed in collaboration with Chevron Production Company U.S.A. as an industrial partner, and incorporates data from the Temblor Formation in Chevron's West Coalinga Field, California. Improved prediction of interwell reservoir heterogeneity was needed to increase productivity and to reduce recovery cost for California's heavy oil sands, which contained approximately 2.3 billion barrels of remaining reserves in the Temblor Formation and in other formations of the San Joaquin Valley.

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Quantitative Methods for Reservoir Characterization and Improved Recovery: Application to Heavy Oil Sands

Improved prediction of interwell reservoir heterogeneity is needed to increase productivity and to reduce recovery cost for California's heavy oil sands, which contain approximately 2.3 billion barrels of remaining reserves in the Temblor Formation and in other formations of the San Joaquin Valley. This investigation involved application of advanced analytical property-distribution methods conditioned to continuous outcrop control for improved reservoir characterization and simulation.

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Basin Analysis of the Mississippi Interior Salt Basin and Petroleum System Modeling of the Jurassic Smackover Formation, Eastern Gulf Coastal Plain

The project objectives are improving access to information for the Mississippi Interior Salt Basin by inventorying data files and records of the major information repositories in the region, making these inventories easily accessible in electronic format, increasing the amount of information available on domestic sedimentary basins through a comprehensive analysis of the Mississippi Interior Salt Basin, and enhancing the understanding of the petroleum systems operating in the Mississippi Interior Salt Basin.

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Increased Oil Production and Reserves Utilizing Secondary/Tertiary Recovery Techniques on Small Reservoirs in the Paradox Basin, Utah

The primary objective of this project was to enhance domestic petroleum production by field demonstration and technology transfer of an advanced-oil-recovery technology in the Paradox Basin, southeastern Utah. If this project can demonstrate technical and economic feasibility, the technique can be applied to approximately 100 additional small fields in the Paradox Basin alone, and result in increased recovery of 150 to 200 million barrels (23,850,000-31,800,000 m3) of oil. This project was designed to characterize five shallow-shelf carbonate reservoirs in the Pennsylvanian (Desmoinesian) Paradox Formation and choose the best candidate for a pilot demonstration project for either a waterflood or carbon-dioxide-(CO2-) miscible flood project. The field demonstration, monitoring of field performance, and associated validation activities will take place within the Navajo Nation, San Juan County, Utah.

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Experimental Investigation of Relative Permeability Upscaling from the Micro-Scale to the Macro-Scale

During this reporting period, shown experimentally that the optical coherence imaging system can acquire information on grain interfaces and void shape for a maximum depth of half a millimeter into sandstone. The measurement of interfacial area per volume (IAV), capillary pressure and saturation in two dimensional micro-models structures has shown the existence of a unique relationship among these hydraulic parameters for different pore geometry. The measurement of interfacial area per volume on a three-dimensional natural sample, i.e., sandstone, has shown the homogeneity of IAV with depth in a sample when the fluids are in equilibrium.

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Experimental Investigation of Relative Permeability Upscaling from the Micro-Scale to the Macro-Scale

During this reporting period, achieved the milestone of using Optical Coherence Imaging (OCI) to image to the back of the first layer of grains in a sandstone sample. This was the first time that OCI was used to image through sandstone. Information on grain geometry was obtained as deep as 400 microns into the sample. This report also describes the work performed to achieve the milestone on the measurement of interfacial area per volume, capillary pressure and saturation in two dimensional micromodels structures that are statistically similar to real porous media. This report contains the first quantitative experimental measurements of interfacial area per volume in any system.

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