AndreaBozzo/ceres-open-data-index huggingface dataset:
INCREASED OIL PRODUCTION AND RESERVES UTILIZING SECONDARY/TERTIARY RECOVERY TECHNIQUES ON SMALL RESERVOIRS IN THE PARADOX BASIN, UTAH

The primary objective of this project is to enhance domestic petroleum production by 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 about 100 additional small fields in the Paradox basin alone, and result in increased recovery of 150 to 200 million barrels of oil. This project is 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-) flood project. The field demonstration, monitoring of field performance, and associated validation activities will take place in the Paradox basin within the Navajo Nation. The results of this project will be transferred to industry and other researchers through a petroleum extension service, creation of digital databases for distribution, technical workshops and seminars, field trips, technical presentations at national and regional professional meetings, and publication in newsletters and various technical or trade journals.

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Successes and Challenges for the Oil Program

Distinguished guests, ladies and gentlemen, good morning. It is a great pleasure to join with the Federal Energy Technology Center (FETC) and our Fossil Energy Headquarters in sponsoring the first DOE Joint Oil and Gas Conference. I am delighted to report over 230 people in attendance. The National Petroleum Technology Office enjoys more and more benefits working with FETC than ever before. I would like to recognize Rita Bajura and her organization for their great support of our office. Thank you, Rita. The technical presentations you will hear in the next few  days were selected for the success and state of development of the projects they describe. Assistant Secretary Gee has already mentioned our pride about the 1999 Hart's Oil and Gas World awards. One of the presentations on the agenda is an awardee: The Best Advanced Recovery Project of the Gulf Coast by Hughes Eastern Corporation of Jackson, Mississippi, who used microflora in oil-bearing formations to selectively plug porous zones to increase oil recoveries in Alabama. Three other DOE projects not represented on the agenda but 1999 Best of the Regions winners, also, are the Best Field Improvement Project of the Pacific by Tidelands Oil Company who, with the City of Long Beach, developed a lower-cost hydrogen sulfide caustic scrubber program in Southern California; the Best Advanced Recovery Project of the Pacific by the University of Utah who developed a technique which restored production to some properties in Kern County, California; and the Best New Technology of the Midcontinent by LeNorman Energy Corporation who, with TRW, designed and installed a very successful alkali-surfactant-polymer flood in the Sho-Vel-Tum Field in Oklahoma. I know representatives are here from some of these winners. How about a round of applause for these projects.

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Greater Green River Basin Production Improvement Project: Rock Island 4-H Well, Table Rock Field, Frontier Formation

The UPR Rock Island 4-H well, located on the north plunge of Table Rock Field in Sweetwater County, Southwest Wyoming (S4-T19N-R97W), is the culmination of 5 years of cooperative government and industry research in the DOE Greater Green River Basin Production Improvement Project, a research partnership between DOE-FETC, Union Pacific Resources and GRI. The primary goal of this project is to explore technologies which could make production of the very large tight gas resources in southwestern Wyoming technically and economically feasible. The Union Pacific Resources Rock Island 4-H well (UPR RI 4-H) appears to be a successful attainment of this goal in the area north of Table Rock Field. Notable milestones achieved in the span of this project include: (1) The reduction of drilling time and expense for vertical wells deeper than 15,000? to less than half of the average time and cost encountered by industry during the last decade. This is critical to making deep, vertical or horizontal tight gas sandstone wells a viable option. (2) One of the deepest horizontal tight gas sandstone wells in the world (>14,950? TVD). (3) Greater than 95% recovery of three of the deepest horizontal cores in the world. (4) One of the highest unstimulated, sustained gas flow capacities (12-14 MMCFD) ever encountered in the tight-gas province of the Cretaceous Frontier Formation in Wyoming. (5) The initiation of ongoing plans for a horizontal drilling effort by industry to evaluate and exploit this previously unattainable resource.

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Figure 3

A typical cross-dipole sonic log from the study area.  From left to right the five tracks are: (1) the minimum and maximum off-diagonal shear-wave energy and depth.  Areas of greatest anisotropy occur where there is the greatest separation between the maximum and minimum curves (areas with a lot of green filling,376 ); (2) the gamma-ray log, well azimuth, well deviation and well diameter (caliper,376 ); (3) the azimuth of the fast shear-wave polarization; (4) the slowness of the fast and slow shear-waves and slowness-based and interval-transit-time-based percentage anisotropy (see color scale at top,376 ); (5) the fast and slow shear-waveforms for one receiver pair and the analysis window (dashed lines).

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Post Waterflood C02 Miscible Flood in Light Oil Fluvial - Dominated Deltaic Reservoirs

The Port Neches CO, flood shown in Figure 1, is a joint operation between the Department of Energy (DOE) and the Texaco Exploration and Production Inc. (TEPI) that has been operating for nearly four years. The project performance during the past year has been adversely affected by several factors including: Water blockage, low residual oil saturation and wellbore mechanical problems. TEPI attempted to test a new procedure in an new fault block using CO, to accelerate primary production in order to improve the primary reserves net present value. the test was abandoned when the discovery well Polk B#39 for the Marg Area 3 was a dry hole. Also, during this period TEPI terminated all new CO, purchases from Cardox for economical reasons, while continuing to recycle produced CO,. A data base for FDD reservoirs for the Louisiana and Texas Gulf Coast Region was developed by LSU and SAIC. This data base includes reservoir parameters and performance data for reservoirs with significant production and OOIP volumes that are amenable to CO, injection. A paper discussing the Port Neches CO, project was presented at the 1996 SPE/DOE Symposium on Improved Oil Recovery.

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Appendix C UPRC - Stratos Fed Unit #1 Special Core Analysis Study

At the request of Mr. Frank Lim of Union Pacific Resources Corporation, Hycal Energy Research Laboratories Ltd conducted an extensive series of special core analysis tests to quantify formation damage mechanisms and reservoir quality and productivity on core samples received from the 1602525 to 161803 ft interval of UPRC Stratos Federal Unit well #1 Tests were conducted to evaluate the formation sensitivity to two crosslinked fracture fluids (Halliburton Frac Gel 2 and BJ Titan Borate HT 4500 to quantify the effects of invasion of these fluids into the formation. Additional tests were conducted to quantify phase trapping potential and determine the water-gas relative permeability characteristics of the formation under consideration. Tests were also conducted on fractured full diameter cores to quantify the effect of closure stress on effective fracture permeability at reservoir conditions and the effect of water influx on micro fracture permeability.

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Revitalizing Aging Oil Fields in South Texas-A Project by the University of  Texas at Austin

Maintaining access to the nation's oil wells is a principal goal of the DOE's Oil Program. Once abandoned, the oil is lost to future production. If kept open, available technologies could be applied to significantly increase production of oil remaining in those reservoirs. In this project, University of Texas researchers are developing methods to locate isolated compartments of unproduced oil. The project is designed to demonstrate the economic advantages of using improved technology to provide optimal well placement. By drilling in the most promising areas to contact remaining unproduced oil production can be increased, and the fields kept operating and accessible for application of future recovery technologies to the estimated 1.6 billion barrels remaining in the Frio sandstone reservoirs.

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Direct Liquefaction Proof-of-Concept Program

This report presents the results of Bench Run PB-02, conducted under the DOE Proof of Concept- Been Option Program in direct coal liquefaction at Hydrocarbon Technologies, Inc. in Lawrenceville, New Jersey. Bench Run PB-02 was the second of the nine runs planned in the POC Bench Option Contract between the US DOE and Hydrocarbon Technologies, Inc. The primary goal of this bench run was to evaluate the hybrid catalyst system, consisting of a dispersed slurry catalyst in one of the hydroconversion reactors and conventional supported extradite catalyst in the other hydroconversion reactor, in a high-low two-stage temperature sequence, similar to the one operated at Wilsonville. This hybrid mode of operation with the high-low temperature sequence was studied during direct liquefaction of coal and in co processing of coal with Hondo resid and/or waste plastics under high space velocity operating conditions. Another important objective of Bench Run PB-02 was to investigate the novel "interstage internal recycle" of the second stage reactor slurry back to the first stage reactor. Other features of the PB-02 included the use of an interstage separator and an in-line fixed bed hydrotreater. In general, it was found during Bench Run PB-02 that the "hybrid type" catalyst system was not effective for obtaining high levels of process performance as the "all dispersed" catalyst system, tested earlier, especially at high coal space velocities. The interstage internal recycle of second stage reactor slurry to the first stage reactor feed line was found to improve cracking of liquefaction products, is exemplified by the increased naphtha products. The addition of small amounts of mixed plastics, representing a typical MSW waste plastic material, was found to improve the hydrogen utilization in both coal conversion and heavy oil hydrocracking reactions, i.e., plastics resulted in improving the overall distillate yield while at the same time reducing the light gas make and chemical hydrogen consumption.

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Greater Green River Basin Production Improvement Project, Rock Island 4-H, Table Rock Field, Frontier Formation

The objective of this effort is to reduce the technical risks and the economic uncertainty standing in the way of increased efficient industry development of the low-permeability (tight) gas resources of the Greater Green River Basin (GGRB) of Wyoming. The overall goal is to encourage development and utilization of the GGRB tight gas resources by industry. Two of the most prolific tight gas reservoirs in the Green River Basin, the Frontier and the Mesaverde, have been extensively developed in the Moxa Arch and Wamsutter Arch areas, respectively, using vertical wells and hydraulic fracture treatments. The deeper, overpressured areas of the basin have been much less developed due to uneconomic production rates. Yet, the Scotia Group 1993 study identified as much as 200 Tcf of deep Frontier and 50 Tcf of deep Mesaverde gas resource potential. Lower than normal reservoir permeability's/porosities and the lack of extensive natural fractures are attributed for the low productivities in previous drilled deep wells. The subject project is intended to reduce these technical risks by testing more effective hydraulic fracturing techniques in a vertical wellbore or to intersect significantly more natural fractures in a horizontal or deviated wellbore. The approach to the project consisted of three phases: Phase I Site Characterization, Phase II Vertical Characterization Well, and Phase III Horizontal Well. Phases I and II resulted in the drilling of the Stratos #1 well (S24-T22N-R107W) through the Second Frontier to a total depth of 16,250 ft. Reservoir characterization and production testing of the Frontier formation determined this location was not favorable for attempting an advanced hydraulic fracture treatment nor for attempting a horizontal lateral. Further site characterization work identified the preferred location and wellbore azimuth for attempting a horizontal lateral to intersect substantial natural fractures in the overpressured Frontier formation on the eastern flank of the Rock Springs Uplift. The blanket marine and lenticular fluvial reservoirs characteristic of the Second Frontier represent prime candidates for a demonstration project that would compare production improvements by drilling, completing and testing of vertical and horizontal, directionally-drilled, wells. Developing techniques to more effectively and economically improve exploitation efficiencies in the Second Frontier has potentially high rewards because this previously unattainable gas resource in the deep Frontier is so large.

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Co2 Huff-n-Puff Process in a Light Oil Shallow Shelf Carbonate Reservoir

The application of cyclic CO2, often referred to as the CO2 Huff-n-Puff'process, may find its niche in the maturing waterfloods of the Permian Basin. Coupling the CO2 H-n-P process to miscible flooding applications could provide the needed revenue to sufficiently mitigate near-term negative cash flow concerns in the capital intensive miscible projects. Texaco Exploration & Production Inc. and the U. S. Department of Energy have teamed up in an attempt to develop the C02 Huff-n-Puff process in the Grayburg/San Andres formation; a light oil, shallow shelf carbonate reservoir within the Permian Basin. This cost-shared effort is intended to demonstrate the viability of this underutilized technology in a specific class of domestic reservoir.

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CO2 Huff-n-Puff Process in a Light Oil Shallow Shelf Carbonate Reservoir

The application of cyclic CO2, often referred to as the CO2 Huff-n-Puff process, may find its niche in the maturing waterfloods of the Permian Basin. Coupling the CO2 H-n-P process to miscible flooding applications could provide the needed revenue to sufficiently mitigate near-term negative cash flow concerns in the capital intensive miscible projects. Texaco Exploration & Production Inc. and the U. S. Department of Energy have teamed up in an attempt to develop the C~ Huff-n-Puff process in the GrayburglSan Andres formation; a light oil, shallow shelf carbonate reservoir within the Pennian Basin. This cost-shared effort is intended to  demonstrate the viability of this underutilized technology in a specific class of domestic reservoir.

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Revitalizing a Mature Oil Play: Strategies for Finding and Producing Unrecovered Oil in Frio Fluvial-Deltaic Sandstone Reservoirs of South Texas

Domestic fluvial-dominated deltaic (FDD) reservoirs contain more than 30 Billion barrels (Bbbl) of remaining oil, more than any other type of reservoir, approximately one-third of which is in danger of permanent loss through premature field abandonments. The U.S.. Department of Energy has placed its highest priority on increasing near-term recovery from FDD reservoirs in order to prevent abandonment of this important strategic resource. To aid in this effort, the Bureau of Economic Geology, The University of Texas at Austin, began a 46-month project in October, 1992, to develop and demonstrate advanced methods of reservoir characterization that would more accurately locate remaining volumes of mobile oil that could then be recovered by recompleting existing wells or drilling geologically targeted infill wells. Reservoirs in two fields within the Frio Fluvial-Deltaic Sandstone (Vicksburg Fault Zone) oil play of South Texas, a mature play which still contains 1.6 Bbbl of mobile oil after producing 1 Bbbl over four decades, were selected as laboratories for developing and testing reservoir characterization techniques. Advanced methods in geology, geophysics, petrophysics, and engineering were integrated to (1) identify probable reservoir architecture and heterogeneity, (2) determine past fluid-flow history, (3) integrate fluid-flow history with reservoir architecture to identify untapped, incompletely drained, and new pool compartments, and (4) identify specific opportunities for near-term reserve growth. To facilitate the success of operators in applying these methods in the Frio play, geologic and reservoir engineering characteristics of all major reservoirs in the play were documented and statistically analyzed. Finally, to assist operators in identifying those reservoirs most prospective for reserve growth, and therefore most worthy of detailed characterization efforts, a quantitative quick-look methodology was developed to prioritize reservoirs in terms of reserve-growth potential. Extensive efforts have been made to transfer the methodology and results of this study to operators within the Frio play, as well as to all operators of fluvial-deltaic reservoirs. One half-day and two full-day workshops were held in cities convenient to Frio operators to demonstrate the methodology through lectures and exercises and answer any questions or concerns about its application. Throughout the course of the study, 16 presentations and 15 publications have been completed to keep operators and researchers across the country, as well as the DOE, informed about project progress and results. Additionally, a microcomputer-based software program titled the Reservoir Characterization Advisor-Fluvial-Deltaic (RCA- FD) has captured the integrated reservoir characterization method and results in a user-friendly format that includes opportunities for input and quick-look prioritization evaluation of operator data.

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ADVANCED RESERVOIR CHARACTERIZATION IN THE ANTELOPE SHALE TO ESTABLISH THE VIABILITY OF CO2 ENHANCED OIL RECOVERY IN CALIFORNIA?S MONTEREY FORMATION SILICEOUS SHALES

The primary objective of this research is to conduct advanced reservoir characterization and modeling studies in the Antelope Shale Reservoir. Characterization studies will be used to determine the technical feasibility of implementing a CO2 enhanced oil recovery project in the Antelope Shale in Buena Vista Hills field. The Buena Vista Hills pilot CO2 project will demonstrate the economic viability and widespread applicability of CO2 flooding in fractured shale reservoirs of the San Joaquin Valley.

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BED-ISOLATION TREATMENTS OF A MATURE WELL IN THE BLUEBELL FIELD OF THE UINTA BASIN, UTAH, THAT HAS UNDERGONE NUMEROUS HIGH-VOLUME SHOTGUN COMPLETIONS

The purpose of the Class I field demonstration program was to increase primary oil production and reserves through improved completion techniques in the Bluebell field, Uinta Basin, Utah. Significant hydrocarbon reserves are believed to remain untapped due to insufficient characterization of the reservoir properties and less-than-optimal well-completion practices. Over one-quarter of the wells drilled in the Bluebell field have been abandoned, and the well abandonment rate is expected to increase as water production increases and oil production declines. Wells in the Bluebell field typically have been completed in a shotgun fashion where 40 or more beds are perforated within a 1,500-foot vertical section of the Tertiary Green River and Colton Formations. During the life of most wells, additional perforated intervals are added and shotgun acid stimulations are applied to all the perforations every few years. The large acid jobs are expensive and the financial return generally declines with each successive treatment. Part of the well demonstration program involved analyzing a mature well using dual burst thermal decay time (TDT) and dipole shear anisotropy (anisotropy) cased-hole logs and then acidizing four beds individually, attempting to avoid treating oil-depleted water-producing beds. Anisotropy and isotope tracer logs were run for post-treatment analysis. The first two acid treatments resulted in communication with intervals above and below the test interval. Swab tests recovered acid water from both intervals. The third and fourth treatments were confined within the test intervals, and oil and water were recovered during swab testing. A bridge plug was placed between the second and third test intervals, eliminating the first two (lowermost) intervals from production. The daily oil production rate was doubled and reservoir modeling indicates that 27,000 barrels of oil was added to the recoverable reserves from a previously perforated but nonproductive bed. This project found the bed-isolation completion technique can be an effective and economic treatment if good cased-hole data are gathered, especially for older wells where the potential incremental increase in oil production no longer justifies the expense of the larger shotgun acid completion. Beds should be selected for treatment using anisotropy and TDT logs to identify beds that are fractured and have relatively low water saturation. The bed-isolation completions should be conducted using a dual packer tool to reduce cost. Both the upper and lower packer should be placed between perforated beds with at least 50 feet of vertical separation between them to reduce the risk of communication behind the casing during the treatment. The isotope tracer log can be useful in evaluating the mechanical aspects of the acid treatment, identifying thief beds, and detecting communication problems behind the casing which can be avoided in future treatments.

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Multi-Well Experiment Plan

New and improved technology is required to enhance gas production from low permeability reservoirs of the  Western United States. These reservoirs constitute a major target for new and supplemental supplies of natural gas. Their development depends upon demonstrating sufficient gas in place and productivity to justify economically the drilling, fracturing and operation of wells.  These reservoir rocks are characterized by lenses of low permeability sand of limited, variable lateral extent and thickness enclosed in a matrix of shale and silty shale. If favorable reservoir conditions can be found in the sand lenses, the problem may become one of intersecting a sufficient number of the gasbearing lenses with an induced fracture to ensure economic production.

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