AndreaBozzo/ceres-open-data-index huggingface dataset:
OPTIMIZING OIL RECOVERY BY DRILLING A TTRILATERAL HORIZONTAL WELL IN A MATURE OFFSHORE CALIFORNIA FIELD

A thorough understanding of reservoir structure is essential to good reservoir management and design of efficient oil recovery processes. In the Federal waters of offshore Santo Borbora, California, the Corpinteria Field's Repetto reservoir comprises multiple layers of unconsolidated sand broken into numerous compartments by faulting. Inadequate understanding of the makeup of this reservoir has resulted in bypassed oil zones, the opening of some wells in zones bearing only water, and loose sand clogging wells. The reservoir is in danger of being abandoned because of these production problems. In this DOE Oil Recovery Field Demonstration Project, Pacific Operators Offshore, Inc. will use innovative drilling and completion strategies based on improved knowledge of the reservoir to increase oil production and reduce the production of sand and water. Accurate emplacement of a horizontal well with multiple lateral extensions into a productive horizon will maximize contact with oil-bearing zone and ovoid unproductive formations,  providing more efficient access to the reservoir's multiple productive layers. Geological and production data and modeling technology will be used to develop the well drilling and completion plan. The horizontal well performance will be monitored to determine the economic feasibility and production potential of applying the technology field wide Publications, presentations, and a workshop conducted by the project operators will transfer the technology to regional producers for use in other reservoirs.

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Low Cost Methods for Finding Tight Gas, Gas Shales and Coalbed Methane

Finding highly productive "sweet spots "in otherwise low permeability sand, shale and coal reservoirs involves delineating areas where natural fractures and gas charged, quality pay coexist. While there is general agreement that finding intense, open sets of natural fractures is essential, accomplishing this ahead of drilling has proven to be a major technical challenge. This paper discusses one approach undertaken by Advanced Resources to address this challenge.

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MEOR - A Low Cost Solution for Enhanced Waterflood Performance

The objective of this project is to demonstrate that waterflood sweep efficiency can be improved by restricting high permeability zones through growth of indigenous bacteria so that water is diverted to low permeability zones which have been inefficiently waterflooded. The successful development and nationwide application of the microbial enhanced oil recovery (MEOR) technology could result in recovery of billions of barrels of bypassed oil which are now either unrecoverable or only recoverable at much higher cost.

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A Small Independent Producer's Design, Construction and Operation of a Flue Gas Injection Project, East Edna Field, Okmulgee County, Oklahoma

Driver Production was one of four companies awarded a grant from the U.S. Department of Energy as a result of a competitive procurement for small independent producers to demonstrate economic application of gas repressurization of oil reservoirs. Driver Production proposed a Flue Gas Injection (N2 and CO2 ) project in a five-spot pattern in the East Edna Field, Okmulgee County, Oklahoma, USA. The paper describes the design, construction, start-up, expansion and operation of a flue gas project that uses produced natural gas as the energy source for combustion and compression. Changing the engine to a larger unit to allow for higher gas injection capacity and for injection at higher pressure demonstrated the need for critical control of flue gas quality to minimize corrosion problems associated with CO2 injection. The project has demonstrated that even small operators can successfully implement gas repressurization to increase oil production from a pressure-depleted reservoir. The project, initiated in 1996, continues to increase oil and natural gas production as long as flue gas is injected. The economics of the project and success to date have prompted the project operator and other operators who have visited and analyzed the project to consider application of flue gas in their small pressure depleted reservoirs.

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Reason for Optimism

I have organized my talk into three sections. First, a review of the condition of our business ? good and bad. Why we believe that being optimistic is not being a lunatic. Optimism as a core belief for the exploration and production business industry. Second, a look at the role of technology in oil and gas production. And third, a brief look at the help we have been getting from our government. The Conference theme is ?Technology Options for Producer Survival.? ?Survival? is not a great word. It implies low self esteem ? low value. I am more interested in prosperity ? not just survival. I believe we are at an inflection point of increased demand for hydrocarbons and increased technology to meet that demand and that new technology will lead the way.

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DOE Natural Gas Program

Good morning. Speaking for my organization, the Federal Energy Technology Center ? FETC for short ? I welcome you to the 1999 Oil and Gas Conference. The theme of this year's conference is ?Technology Options for Producer Survival.? During this conference, you will hear about the new and improved technologies that are evolving from DOE-sponsored R&D. We in DOE hope that you will find this information useful; we will consider this conference a success if your bottom line benefits because of the research that we are sponsoring. In my paper, keeping with the theme of this conference, I'd like to share with you what we are doing to develop and transfer new technologies to domestic operators and the service industry ? technologies that reduce the cost of finding and producing natural gas, technologies that ensure that the U.S. continues to have an affordable supply of clean-burning natural gas. I would also like to share with you DOE?s vision of an integrated natural gas program, a program encompassing all aspects of natural gas: exploration and production, transport, storage, distribution, and use.

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Proceedings of the 1999 Oil & Gas Conferences Technology Options for Producer Survival

The 1999 Oil & Gas Conference was cosponsored by the U.S. Department of Energy (DOE), Office of Fossil Energy, Federal Energy Technology Center (FETC) and National Petroleum Technology Office (NPTO) on June 28 to 30 in Dallas, Texas. DOE sponsors technology research and development for the oil and natural gas industries. Periodically, DOE presents the results of this research in a conference format to provide technology transfer to interested parties and to keep the public informed. The Oil & Gas Conference theme, Technology Options for Producer Survival, reflects the need for development and implementation of new technologies to ensure an affordable, reliable energy future.

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The Hughes Eastern Project - Using a Reservoir's Natural Microbes to Improve Oil Recovery

The Hughes Eastern Corporation project is demonstrating how naturally occurring varieties of microbes in an oil reservoir can be used to increase crude oil production. Supplied with the proper nutrients, these bacteria can grow rapidly. Whereas certain strains can be used to thin oil so that it will move more easily through the reservoir rock, other types of microbes can form gels to change the flow paths of water and oil through the formation. Hughes Eastern is using these latter types to effect beneficial changes in reservoir fluid flow patterns. In the North Blowhorn Creek field near Vernon, Alabama, as in many domestic fields, oil is being produced by waterflooding-injecting water to force oil towards producing wells. After many years, portions of the reservoir have been "swept" of much of the remaining producible oil, but other areas, bypassed during the waterflooding, still contain significant amounts of "unswept" oil. Hughes will use the natural microbes to plug the water-swept parts of the reservoir, thereby diverting injected water to the bypassed oil-containing zones. Core samples from Iwo new wells drilled in early 1994 indicated that this area of the reservoir had not been swept by the waterflood and contained significant amounts of producible oil. Laboratory testing also showed that, when water containing common plant fertilizers was passed through the core samples, the natural microbes grew, plugged the pore spaces in the rock, and increased the resistance to water flow. Further testing helped researchers learn what mixture of fertilizer and water best stimulated microbial growth. Hughes began injecting the selected fertilizer mixes in four well patterns in late 1994 and early 1995. Staff are monitoring each pattern's injection capacity and oil and water production rates, and checking for indications of microbial effects. Initial production increases were noted, but major changes are not expected for some time.

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Identification and Evaluation of Fluvial-Dominated Deltaic (Class-I Oil) Reservoirs in Oklahoma

The Oklahoma Geological Survey (OGS), the Geo Information Systems department, and the School of Petroleum and Geological Engineering at the University of Oklahoma engaged in a five-year program to identify and address Oklahoma's oil recovery opportunities in fluvial dominated deltaic (FDD) reservoirs. This was accomplished under Cooperative Agreement No. DE-FC22-93BC14956. The program included a systematic and comprehensive collection and evaluation of information on all FDD oil reservoirs in Oklahoma and the recovery technologies that have been (or could be) applied to those reservoirs successfully. This data collection and evaluation effort was the foundation for an aggressive, multifaceted technology transfer program that was designed to support all of Oklahoma's oil industry. However, particular emphasis of this program was directed toward smaller companies and independent operators in order to help them maximize oil production from FDD reservoirs. Specifically, this project identified all FDD oil reservoirs in the State; grouped those reservoirs into plays that have similar depositional and geologic histories; collected, organized and analyzed all available data; performed characterization and simulation studies on selected reservoirs in each play; and implemented a technology transfer program that targeted operators of FDD reservoirs. These elements of the FDD program provided the kind of assistance that could allow operators to extend the life of existing wells with the ultimate objective of recovering more oil. The execution of this project was approached in phases. The first phase began in January, 1993 and consisted of planning, play identification and analysis, data acquisition, database development, and computer systems design. By the middle of 1994, many of these tasks were completed or nearly finished including the identification of all FDD reservoirs in Oklahoma, data collection, and defining play boundaries. Later in 1994, a preliminary workshop schedule was developed for project implementation and technology transfer activities. In early 1995, a specific workshop agenda was formatted and play publication requirements were identified. Later in 1995, the play workshop and publication series were initiated with the Morrow play in June and the Booch play in September. The remaining six play workshops were completed through 1996 and 1997, with the project ending on December 31, 1997.

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Appendix 12 DSGC - Geochemical Report, Rock Island #4-H

Black material on a fracture face of a conventional core from 15,424.55 MD in the Rock-Island 4H well was analyzed to determine its affinity and significance. A scraping of the black material was analyzed for organic carbon content and with Rock-Eval Pyr9lysis. Some free hydrocarbons were present and the sample was then analyzed with St pyrolysis gc (thermal extraction) to determine their composition. Finally, a whole rock polished section of the core at the fracture location was analyzed with reflected light microscopy to determine the distribution of the black material in the sample.

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Technologies Under Development: "Design and Development of Gas-Liquid Cylindrical Cyclone Compact Separators for Three-Phase Flow"

For many years, the Petroleum Industry has relied mainly on the conventional vessel-type separators. They are bulky, heavy and expensive in capital, installation and operation. Due to economic and operational pressures, the petroleum industry has recently shown interest in the development of innovative alternatives to the  conventional separators. One such alternative is the Gas-liquid Cylindrical Cyclone (GLCC). Unlike the conventional vessel type separators, the GLCC is simple, compact, low weight, low-cost, requires little maintenance, and is easy to install and operate. It is therefore gaining popularity as an easy-to-operate economically attractive, alternative to the conventional separator. The development ranking of the various separation technology alternatives are shown schematically in Fig. 1. As shown in this figure, conventional vessel-type separators have reached their maturity, except for some minor improvements that are being incorporated, such as new developments of internal devices and control systems. Large diameter vertical cyclones and hydro-cyclones have also been used by the industry for some time. However, recent trends in development are focused towards new type of compact separators such as the GLCC

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Advanced Fracturing Technologies for Marginal Oil and Gas Wells

The fundamental objective of the project is to demonstrate the application and economic feasibility of ?new and novel? fracturing technologies for restoring the deliverability of existing underground gas storage wells. Within this primary objective, several tactical objectives are as follows: - Identify ?new and novel? fracture stimulation methods that hold potential for gas storage wells. -Demonstrate their application, including treatment design, implementation and results. -Evaluate their economic performance as compared to ?typical? (non-fracturing) stimulation practices of gas storage operators, such as blowing/washing or mechanical cleaning of the wellbore, reperforating, water/solvent washes, and acidizing.

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Discrete Feature Network Methods for IOR in Heterogeneous Reservoirs

Heterogeneities such as fractures, faults, sand/sandstone interbeds, and solution features play a key role in controlling the flow of reservoir fluids (oil and water) and injected materials (water, steam, surfactant and gel) to and from wells. Critical improvements in oil recovery efficiency can be achieved through an improved understanding of the connectivity of these features. This paper describes the development of discrete feature network (DFN) methods to support IOR activities in heterogeneous and fractured dolomite and sandstone reservoirs. DFN models have been developed to identify the key discrete features that control flow and connectivity, such that the models can be used directly in the design of IOR activities. This paper describes DFN approach to support IOR activities such as: 1. surfactant treatments to enhance a gravity stable recovery process, 2. waterflood displacement, 3. alternative gel treatments, 4. improved targeting of water injection, 5. horizontal drilling to connect with low recovery portions of the reservoir, 6. selective reduction in water cycling by improved gel conformance treatment design and placement, and 7. improved completion placement and stimulation for oil recovery under depletion mechanisms.

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NEW HIGH STRENGTH AND FASTER DRILLING TSP DIAMOND CUTTERS

The objective of this project is to develop advanced drilling systems which employ thermally stable diamond (TSP) drill bits. New TSP diamond cutters are to be capable of reducing overall system costs by increasing rates of penetration and bit life in abrasive and hard rock applications. Improved performance of unique TSP diamond cutters has been demonstrated in the laboratory, and field tests are planned. The CSS (continuous shelf sharpening) cutter design produced under this DOE FETC project has demonstrated the potential to double both rate of penetration and bit life. Abrasive and hard rock drilling costs could be reduced by about 15%, and the overall drilling project cost could be reduced by 7.5%. Thus, there is the opportunity to allow economic development of remaining natural gas and oil resources in the U.S., and strengthen the development of the U.S. Drilling Industry.

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NATURAL GAS HYDRATES STORAGE PROJECT PHASE II. CONCEPTUAL DESIGN AND ECONOMIC STUDY

DOE Contract DE-AC26-97FT33203 studied feasibility of utilizing the natural-gas storage property of gas hydrates, so abundantly demonstrated in nature, as an economical industrial process to allow expanded use of the clean-burning fuel in power plants. The laboratory work achieved breakthroughs: (1) Gas hydrates were found to form orders of magnitude faster in an unstirred system with surfactant-water micellar solutions. (2) Hydrate particles were found to self-pack by adsorption on cold metal surfaces from the micellar solutions. (3) Interstitial micellar-water of the packed particles were found to continue forming hydrates. (4) Aluminum surfaces were found to most actively collect the hydrate particles.

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DETERMINATION OF MINIMUM WATER-AIR FLOW RATE REQUIRED FOR EFFECTIVE CUTTINGS TRANSPORT IN HIGH ANGLE AND HORIZONTAL WELLS.

1. Determine experimentally the minimum flow rates for water and air that guarantee the hole cleaning while drilling horizontal and near horizontal sections. 2. Develop charts that help to establish minimum requirements of air and water injection rates to plan drilling of high angle and horizontal sections, using air-water system as drilling fluid (see Fig. 1)

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NATURAL GAS HYDRATES STORAGE PROJECT

Since economical and environmental conditions could be positively affected by greater use of natural gas, especially for peak-loading events of power plants, the feasibility of overcoming a major impediment of safe, aboveground storage in heavily populated areas was sought in the work funded by DE-AC26-97FT33203. Principal deterrent to utilizing natural gas to its fullest is the difficulty of onsite storage; principal incentive to utilizing natural gas to its fullest is its clean-burning quality and its relatively low cost.

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A Well Completion Technique for Controlling Unconsolidated Sand Formations by Using Steam

This paper will discuss a competitively-priced and superior well completion technique for controlling unconsolidated sand formations by injecting high temperature and pressure steam to geochemically bond the sand grains in the perforation tunnels. Wells applying this method are cased and cemented through the desired producing interval and completed with only a few small diameter perforations. This well completion technique has been applied in 12 horizontal wells and 22 vertical wells with over 90% of the wells capable of production or injection after two years. The use of the hot alkaline / steam sand consolidation technique to complete wells is based on the geochemical bonding of unconsolidated formation sand grains with a lattice of primarily high temperature complex synthetic silicate cements and possibly other lower temperature precipitates such as silica cements and carbonate scales. The complex silicate cements and other mineral precipitates are created by the high temperature and high alkaline pH steam condensate which preferentially dissolves sand grains with high specific surface area. The injected fluids rapidly lose heat to the formation and various cements precipitate with changes in temperature, alkalinity, and contact time. The lattice of cement bonds are created by the relatively high volume and high velocity steam vapor phase which dissipates through the near-wellbore region quickly and carries away excess cements and other precipitates where they do not adversely affect formation porosity and permeability. The wells completed with this technique have equivalent or higher productivity and injectivity than wells completed with opened-hole, gravel-packed slotted-liner completions. In addition, this technology can significantly lower drilling and completion costs, improves fluid entry or injection profile control, provides a low cost means to eliminate unwanted completion intervals, and provides flexibility to use the wells interchangeably as producers or injectors.

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PETROLEUM POTENTIAL OF SOUTHWESTERN WYOMING AND ADJACENT AREAS

Southwestern Wyoming and adjacent areas in n6rthwestern Colorado and northeastern Utah have had a favorable depositional and structural history for the formation and accumulation of significant amounts of hydrocarbons. The 89,420 cu mi (373,685 cu km) sedimentary package contains sediments of all periods except the Silurian. Hydrocarbons are produced from all but Ordovician and Devonian age sediments in a variety of structural and stratigraphic traps. An optimistic future is predicted to greatly improve the estimated original in place reserves of I .R billion bbl of oil and 7.3 trillion cu ft of gas, by deeper drilling on producing structures, and presently undefined structural and stratigraphic traps in the deeper portions of the basins.

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CUTTINGS TRANSPORT WITH FOAM IN HORIZONTAL AND INCLINED WELLBORES

OBJECTIVES 1. To investigate foam rheology and flow behavior in pipe and annulus. 2. To determine (experimentally) and to predict (numerically) frictional pressure losses (with and without cuttings) and volumetric requirements (injection rate, injection pressure and backpressure) for effective cuttings transport with foam flow in inclined and horizontal wellbores

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Application of Reservoir Characterization and Advanced Technology to Improve Recovery and Economics in a Lower Quality Shallow Shelf San Andres Reservoir

During this quarter the porosity and permeability profile between wells created by integrating core, log and Cross well seismic data were used to build variograms. Using geostatistical methods, these variograms can be used to generate a spatial distribution or the reservoirs petrophysical properties. Modifications were completed on the CO2 distribution system to accommodate the injection of sour CO2 which was initiated in February 1999.

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Welcome to Technology Options for Producers? Survival.

It is a pleasure to be here with you this morning. I appreciate the opportunity to open this conference. As you know, the subtitle for this conference is ?technology options for producers? survival.? For better or worse, it is an appropriate title ? particularly when we emphasize the last word, "survival."For the last several months, many of you, and many of your colleagues , have had to deal with that word, "survival." You have ridden a roller coaster of prices ? again, like you did in the mid-80s and again in the early 90s. This time, however, the declines were steeper and more severe than at any time in post-war memory. And the upturns have been gradual and filled with uncertainty.

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Increasing Heavy Oil Reserves in The Wilmington Oil Field Through Advanced Reservoir Characterization And Thermal Production Technologies

The objective of this project is to increase the recoverable heavy oil reserves within sections of the Wilmington Oil Field, near Long Beach, California. This is realized through the testing and application of advanced reservoir characterization and thermal production technologies. It is hoped that the successful application of these technologies will result in their implementation throughout the Wilmington Field and, through technology transfer, will be extended to increase the recoverable oil reserves in other slope and basin clastic (SBC) reservoirs.

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