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Note: This page contains sample records for the topic "horizontal wells drilling" from the National Library of EnergyBeta (NLEBeta).
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1

PREDICTION OF CUTTINGS BED HEIGHT WITH COMPUTATIONAL FLUID DYNAMICS IN DRILLING HORIZONTAL AND HIGHLY DEVIATED WELLS  

E-Print Network (OSTI)

Louisiana State University Abstract In oil well drilling, the efficient transport of drilled cuttings from pipe and excessive frictional pressure losses while drilling directional and horizontal oil wellsPREDICTION OF CUTTINGS BED HEIGHT WITH COMPUTATIONAL FLUID DYNAMICS IN DRILLING HORIZONTAL

Ullmer, Brygg

2

Drilling fluid technology for horizontal wells to protect the formations in unconsolidated sandstone heavy oil reservoirs  

Science Journals Connector (OSTI)

Major factors that cause damage in drilling in unconsolidated sandstone heavy oil reservoirs include: invasion of solids in drilling fluid, incompatibility between the liquid phase of drilling fluid and crude oil, and hydration and expansion of reservoir clay minerals. Therefore, a solid-free weak gel drilling fluid system for horizontal wells to protect the formations was developed that contains seawater + 0.1%–0.2% NaOH + 0.2% Na2CO3+ 0.7% VIS + 2.0% FLO + 2.0% JLX, weighed with \\{KCl\\} or sodium formate. The drilling fluid system has unique rheological properties, temporally independent gel strength, and excellent lubricating and inhibition performance. It is compatible with formation fluids, it not only meets the needs of horizontal well drilling, but also effectively protects the reservoir. The technique is well performed in tens of horizontal wells in offshore oilfields, such as WC13-1, BZ34-1, NP35-2, and BZ25-1 oilfields.

Yue Qiansheng; Liu Shujie; Xiang Xingjin

2010-01-01T23:59:59.000Z

3

Hydraulic Fracturing and Horizontal Gas Well Drilling Reference List Updated December 7, 2011  

E-Print Network (OSTI)

Hydraulic Fracturing and Horizontal Gas Well Drilling Reference List Updated December 7, 2011 of Hydraulic Fracturing in the Shale Plays (2010). Tudor Pickering Holt & Co with Reservoir Research Partners, with a thoughtful discussion Plan to Study the Potential Impacts of Hydraulic Fracturing on Drinking Water Resources

Manning, Sturt

4

Hydraulic Fracturing and Horizontal Gas Well Drilling Reference List Updated June 23, 2011  

E-Print Network (OSTI)

Hydraulic Fracturing and Horizontal Gas Well Drilling Reference List Updated June 23, 2011 of Hydraulic Fracturing in the Shale Plays (2010). Tudor Pickering Holt & Co with Reservoir Research Partners, with a thoughtful discussion Draft Plan to Study the Potential Impacts of Hydraulic Fracturing on Drinking Water

5

A parametric study on the benefits of drilling horizontal and multilateral wells in coalbed methane reservoirs  

SciTech Connect

Recent years have witnessed a renewed interest in development of coalbed methane (CBM) reservoirs. Optimizing CBM production is of interest to many operators. Drilling horizontal and multilateral wells is gaining Popularity in many different coalbed reservoirs, with varying results. This study concentrates on variations of horizontal and multilateral-well configurations and their potential benefits. In this study, horizontal and several multilateral drilling patterns for CBM reservoirs are studied. The reservoir parameters that have been studied include gas content, permeability, and desorption characteristics. Net present value (NPV) has been used as the yard stick for comparing different drilling configurations. Configurations that have been investigated are single-, dual-, tri-, and quad-lateral wells along with fishbone (also known as pinnate) wells. In these configurations, the total length of horizontal wells and the spacing between laterals (SBL) have been studied. It was determined that in the cases that have been studied in this paper (all other circumstances being equal), quadlateral wells are the optimum well configuration.

Maricic, N.; Mohaghegh, S.D.; Artun, E. [Chevron Energy Technology Co., Houston, TX (USA)

2008-12-15T23:59:59.000Z

6

Drilling Sideways -- A Review of Horizontal Well Technology and Its Domestic Application  

Gasoline and Diesel Fuel Update (EIA)

TR-0565 TR-0565 Distribution Category UC-950 Drilling Sideways -- A Review of Horizontal Well Technology and Its Domestic Application April 1993 Energy Information Administration Office of Oil and Gas U.S. Department of Energy Washington, DC 20585 This report was prepared by the Energy Information Administration, the independent statistical and analytical agency within the Department of Energy. The information contained herein should not be construed as advocating or reflecting any policy position of the Department of Energy or any other organization. Contacts This report was prepared by the Energy Information Administration, Office of Oil and Gas, under the general direction of Diane W. Lique, Director of the Reserves and Natural Gas Division, Craig H. Cranston, Chief of the Reserves and Production Branch, and David F. Morehouse, Senior Supervisory Geologist. Information regarding

7

Horizontal well construction/completion process in a Gulf of Mexico unconsolidated sand: development of baseline correlations for improved drill-in fluid cleanup practices.  

E-Print Network (OSTI)

??This thesis examines, in detail, the procedures and practices undertaken in the drilling and completion phases of a Gulf of Mexico horizontal well in an… (more)

Lacewell, Jason Lawrence

2012-01-01T23:59:59.000Z

8

Geological aspects of drilling horizontal wells in steam flood reservoirs, west side, southern San Joaquin Valley, California  

SciTech Connect

Shell Western E P Inc. has drilled 11 horizontal wells in four mature steam floods in the Coalinga, South Belridge, and Midway-Sunset fields. Two medium radius wells are producing from the Pliocene Etchegoin Formation in Coalinga. One medium radius well is producing from the Pleistocene Tulare Formation in South Belridge field. Three short radius and five medium radius wells are producing from the upper Miocene, Sub-Hoyt and Potter sands in Midway-Sunset field. Horizontal wells at the base of these reservoirs and/or structurally downdip near the oil-water contact are ideally suited to take advantage of the gravity drainage production mechanism. Reservoir studies and production experience have shown these horizontal wells should increase reserves, improve recovery efficiency, improve the oil-steam ratio, and improve project profitability. Geological considerations of targeting the wells vary between fields because of the different depositional environments and resulting reservoir characteristics. The thin sands and semicontinuous shales in the Tulare Formation and the Etchegoin Formation require strict structural control on the top and base of the target sand. In the Sub-Hoyt and Potter sands, irregularities of the oil-water contact and sand and shale discontinuities must be understood. Logging and measurement while drilling provide geosteering capability in medium radius wells. Teamwork between all engineering disciplines and drilling and producing operations has been critical to horizontal well success.

Crough, D.D.; Holman, M.L.; Sande, J.J. (Shell Western E P Inc., Bakersfield, CA (United States))

1994-04-01T23:59:59.000Z

9

Horizontal well IPR calculations  

SciTech Connect

This paper presents the calculation of near-wellbore skin and non-Darcy flow coefficient for horizontal wells based on whether the well is drilled in an underbalanced or overbalanced condition, whether the well is completed openhole, with a slotted liner, or cased, and on the number of shots per foot and phasing for cased wells. The inclusion of mechanical skin and the non-Darcy flow coefficient in previously published horizontal well equations is presented and a comparison between these equations is given. In addition, both analytical and numerical solutions for horizontal wells with skin and non-Darcy flow are presented for comparison.

Thomas, L.K.; Todd, B.J.; Evans, C.E.; Pierson, R.G.

1996-12-31T23:59:59.000Z

10

Evaluation of polymer free drill-in fluids for use in high productivity, horizontal well completions  

E-Print Network (OSTI)

Advancements in deepwater drilling have necessitated the use of more specialized reservoir drill-in fluids (RDIF). These RDIFs must exhibit unique rheological properties while minimizing formation damage. Xanthan gum biopolymer is generally used...

Falla Ramirez, Jorge H

2012-06-07T23:59:59.000Z

11

Horizontal well construction/completion process in a Gulf of Mexico unconsolidated sand: development of baseline correlations for improved drill-in fluid cleanup practices  

E-Print Network (OSTI)

This thesis examines, in detail, the procedures and practices undertaken in the drilling and completion phases of a Gulf of Mexico horizontal well in an unconsolidated sand. In particular, this thesis presents a detailed case history analysis...

Lacewell, Jason Lawrence

2012-06-07T23:59:59.000Z

12

Well drilling apparatus  

SciTech Connect

A drill rig for drilling wells having a derrick adapted to hold and lower a conductor string and drill pipe string. A support frame is fixed to the derrick to extend over the well to be drilled, and a rotary table, for holding and rotating drill pipe strings, is movably mounted thereon. The table is displaceable between an active position in alignment with the axis of the well and an inactive position laterally spaced therefrom. A drill pipe holder is movably mounted on the frame below the rotary table for displacement between a first position laterally of the axis of the well and a second position in alignment with the axis of the well. The rotary table and said drill pipe holder are displaced in opposition to each other, so that the rotary table may be removed from alignment with the axis of the well and said drill pipe string simultaneously held without removal from said well.

Prins, K.; Prins, R.K.

1982-09-28T23:59:59.000Z

13

Laboratory tests to evaluate and study formation damage with low-density drill-in fluids (LDDIF) for horizontal well completions in low pressure and depleted reservoirs  

E-Print Network (OSTI)

The increasing number of open hole horizontal well completions in low-pressure and depleted reservoirs requires the use of non-damaging low-density drill-in fluids (LDDIF) to avoid formation damage and realize optimum well productivity. To address...

Chen, Guoqiang

2012-06-07T23:59:59.000Z

14

Wayne field: A horizontal drilling case study  

SciTech Connect

Beginning in the spring of 1994, studies of Wayne field located on the northeastern flank of the Williston Basin were initiated to determine the feasibility of using horizontal drilling to increase recoverable reserves in the field. The Wayne subinterval is one of several shoaling-upwards cycles within the Mission Canyon Formation of the Mississippian Madison Group. The reservoir pay averages 24% porosity, 100 millidarcys permeability, and 50% water saturation. Vertical wells, since field discovery in 1957, typically IP for 70 bopd and 20% water with a rapid decline within a few months to 10 bopd and 90% water. This type of well performance is characteristic of severe water coning for which horizontal development can help to minimize. In late 1994 and early 1995 the Ballantyne Hedges No.7H and GeoResources O. Fossum No.H1 were drilled. The wells recorded IP`s of 280 bopd/5 bwpd and 390 bopd/80 bwpd respectively. After six months of production both wells stabilized at approximately 110 bopd with a 35% water cut. Projections indicate that each horizontal well will recover 250,000 bbls of oil as compared to 115,000 bbls for an average vertical well and will do so in half the time. These early results provide a significant improvement over the vertical production and would seem to be reducing water coning. Three more horizontal wells are planned for the fourth quarter of 1995.

Jennings, J.B. [GeoResources, Inc., Williston, ND (United States); Johnson, R.P. [Harris, Brown, & Kiemer, Inc., Bismarck, ND (United States)

1996-06-01T23:59:59.000Z

15

Bakken shale typifies horizontal drilling success  

SciTech Connect

Given the favorable production response that has been obtained from horizontal drilling in vertical- fractured reservoirs such as the Bakken shale and, more recently, the Austin chalk, industry interest in this technology has mushroomed in the U.S. Indeed, it is difficult to find a good-sized oil company these days that is not involved in a horizontal drilling project or is giving it serious consideration. In response to growing evidence of successful field applications, the realization is dawning on the investment community that horizontal drilling represents a significant technological development with positive implications for both the exploration and production business, and the oilfield services industry.

Leibman, P.R. (Petrie Parkman and Co., Denver, CO (US))

1990-12-01T23:59:59.000Z

16

Formation damage studies of lubricants used with drill-in fluids systems on horizontal open-hole wells  

E-Print Network (OSTI)

Tests were conducted to evaluate the effect of lubricants in formation damage. Two types of lubricants were tested along with two types of drill-in fluids. The DIF's tested included a sized-calcium carbonate (SCC) and a sized-salt (SS). Also a set...

Gutierrez, Fernando A

2012-06-07T23:59:59.000Z

17

Application of horizontal drilling to tight gas reservoirs  

SciTech Connect

Vertical fractures and lithologic heterogeneity are extremely important factors controlling gas flow rates and total gas recovery from tight (very low permeability) reservoirs. These reservoirs generally have in situ matrix permeabilities to gas of less than 0.1 md. Enhanced gas recovery methods have usually involved hydraulic fracturing; however, the induced vertical hydraulic fractures almost always parallel the natural fracture and may not be an efficient method to establish a good conduit to the wellbore. Horizontal drilling appears to be an optimum method to cut across many open vertical fractures. Horizontal holes will provide an efficient method to drain heterogeneous tight reservoirs even in unfractured rocks. Although many horizontal wells have now been completed in coalbed methane and oil reservoirs, very few have been drilled to exclusively evaluate tight gas reservoirs. The U.S. Department of Energy (DOE) has funded some horizontal and slanthole drilling in order to demonstrate the applicability of these techniques for gas development. Four DOE holes have been drilled in Devonian gas shales in the Appalachian basin, and one hole has been drilled in Upper Cretaceous tight sandstones in the Piceance basin of Colorado. The Colorado field experiment has provided valuable information on the abundance and openness of deeply buried vertical fractures in tight sandstones. These studies, plus higher gas prices, should help encourage industry to begin to further utilize horizontal drilling as a new exploitation method for tight gas reservoirs.

Spencer, C.W. (U.S. Geological Survey, Lakewood, CO (United States)); Lorenz, J.C. (Sandia National Labs., Albuquerque, NM (United States)); Brown, C.A. (Synder Oil Co., Denver, CO (United States))

1991-03-01T23:59:59.000Z

18

Acid Placement in Acid Jetting Treatments in Long Horizontal Wells  

E-Print Network (OSTI)

In the Middle East, extended reach horizontal wells (on the order of 25,000 feet of horizontal displacement) are commonly acid stimulated by jetting acid out of drill pipe. The acid is jetted onto the face of the openhole wellbore as the drill pipe...

Sasongko, Hari

2012-07-16T23:59:59.000Z

19

1982 geothermal well drilling summary  

SciTech Connect

This summary lists all geothermal wells spudded in 1982, which were drilled to a depth of at least 2,000 feet. Tables 1 and 2 list the drilling information by area, operator, and well type. For a tabulation of all 1982 geothermal drilling activity, including holes less than 2,000 feet deep, readers are referred to the February 11, 1983, issue of Petroleum Information's ''National Geothermal Service.'' The number of geothermal wells drilled in 1982 to 2,000 feet or more decreased to 76 wells from 99 ''deep'' wells in 1981. Accordingly, the total 1982 footage drilled was 559,110 feet of hole, as compared to 676,127 feet in 1981. Most of the ''deep'' wells (49) completed were drilled for development purposes, mainly in The Geysers area of California. Ten field extension wells were drilled, of which nine were successful. Only six wildcat wells were drilled compared to 13 in 1980 and 20 in 1981, showing a slackening of exploration compared to earlier years. Geothermal drilling activity specifically for direct use projects also decreased from 1981 to 1982, probably because of the drastic reduction in government funding and the decrease in the price of oil. Geothermal power generation in 1982 was highlighted by (a) an increase of 110 Mw geothermal power produced at The Geysers (to a total of 1,019 Mw) by addition of Unit 17, and (b) by the start-up of the Salton Sea 10 Mw single flash power plant in the Imperial Valley, which brought the total geothermal electricity generation in this area to 31 Mw.

Parmentier, P.P.

1983-08-01T23:59:59.000Z

20

Using LWD to drill horizontally above oil/water contacts  

SciTech Connect

This paper reports on the first successful horizontal oil well in the state of Arkansas which helped increase production from one Smackover field. This completion utilized resistivity logging during drilling and improved drainage patterns in the thin oil column, resulting in more effective reserve depletion. Midway Field Unit is located in Lafayette County of southwestern Arkansas. In addition to being the first successful horizontal well in Arkansas, Midway Field Units well 2-15 was also American Exploration's first horizontal well. The well was brought on line February 28, 1991 flowing 380 bopd and no water, and is currently producing oil on rod pump at about 200 bpd. This completion increased field production by 27%. A second horizontal well was drilled and the third completion of this type is now under way. Additional horizontal wells are planned for Midway field based on the success of the first two wells. This approach to depleting reserves in fields with by-passed reserves and thin oil columns like the Midway Unit has proven to be cost effective and efficient.

Trusty, J.E.; Emmet, L.R. (American Exploration Co., Houston, TX (US))

1992-03-01T23:59:59.000Z

Note: This page contains sample records for the topic "horizontal wells drilling" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


21

Pressure analysis for horizontal wells  

SciTech Connect

This paper presents horizontal-well test design and interpretation methods. Analytical solutions are developed that can be handled easily by a desktop computer to carry out design as well as interpretation with semilog and log-log analysis. These analytical solutions point out the distinctive behavior of horizontal wells: (1) at early time, there is a circular radial flow in a vertical plane perpendicular to the well, and (2) at late time, there is a horizontal pseudoradial flow. Each type of flow is associated with a semilog straight line to which semilog analysis has to be adapted. The horizontal pseudoradial flow takes into account a pseudoskin depending on system geometry, which is a priori defined and estimated. Practical time criteria are proposed to determine the beginning and the end of each type of flow and to provide a guide to semilog analysis and well test design. The authors study the behavior of uniform-flux or infinite-conductivity horizontal wells, with wellbore storage and skin. The homogeneous reservoir is infinite or limited by impermeable or constant-pressure boundaries. A method is also outlined to transform all our solutions for homogeneous reservoirs into corresponding solutions for double-porosity reservoirs.

Davlau, F.; Mouronval, G.; Bourdarot, G.; Curutchet, P.

1988-12-01T23:59:59.000Z

22

Horizontal drilling the Bakken Formation, Williston basin: A new approach  

SciTech Connect

Horizontal drilling is an attractive new approach to exploration and development of the Mississippian/Devonian Bakken Formation in the southwestern part of North Dakota. This drilling technique increases the probability of success, the profit potential, the effective drainage area maximizing recoverable reserves, and the productivity by encountering more natural occurring fractures. The target formation, the Mississippian/Devonian Bakken, consists of three members in an overlapping relationship, a lower organic-rich black shale, a middle siltstone/limestone, and an upper organic-rich black shale. It attains a maximum thickness of 145 ft and thins to a feather edge along its depositional limit. Considered to be a major source rock for the Williston basin, the Bakken is usually overpressured where productive. Overpressuring is attributed to intense hydrocarbon generation. Reservoir properties are poor with core fluid porosities being generally 5% or less and permeabilities ranging from 0.1 to 0.2 md. The presence of natural fractures in the shale are necessary for production. Two types of fractures are associated with Bakken reservoirs: large vertical fractures (of tectonic origin) and microfractures (probably related to hydrocarbon generation). An economic comparison between horizontal and vertical wells show that well completion costs are approximately two times higher (average costs; $1,500,000 for a horizontal to $850,000 for a vertical) with average payout for horizontal wells projected to occur in half the time (1.5 yr instead of 3.4 yr). Projected production and reserves are considered to be 2 to 4 times greater from a horizontal well.

Lefever, J.A. (North Dakota Geological Survey, Grand Forks (USA))

1990-05-01T23:59:59.000Z

23

Downhole Temperature Prediction for Drilling Geothermal Wells  

SciTech Connect

Unusually high temperatures are encountered during drilling of a geothermal well. These temperatures affect every aspect of drilling, from drilling fluid properties to cement formulations. Clearly, good estimates of downhole temperatures during drilling would be helpful in preparing geothermal well completion designs, well drilling plans, drilling fluid requirements, and cement formulations. The thermal simulations in this report were conducted using GEOTEMP, a computer code developed under Sandia National Laboratories contract and available through Sandia. Input variables such as drilling fluid inlet temperatures and circulation rates, rates of penetration, and shut-in intervals were obtained from the Imperial Valley East Mesa Field and the Los Alamos Hot Dry Rock Project. The results of several thermal simulations are presented, with discussion of their impact on drilling fluids, cements, casing design, and drilling practices.

Mitchell, R. F.

1981-01-01T23:59:59.000Z

24

Borehole Stability Analysis of Horizontal Drilling in Shale Gas Reservoirs  

Science Journals Connector (OSTI)

Serious wellbore instability occurs frequently during horizontal drilling in shale gas reservoirs. The conventional forecast model of in ... not suitable for wellbore stability analysis in laminated shale gas for...

Jun-Liang Yuan; Jin-Gen Deng; Qiang Tan; Bao-Hua Yu…

2013-09-01T23:59:59.000Z

25

Fraced horizontal well shows potential of deep tight gas  

SciTech Connect

Successful completion of a multiple fraced, deep horizontal well demonstrated new techniques for producing tight gas sands. In Northwest Germany, Mobil Erdgas-Erdoel GmbH drilled, cased, and fraced the world`s deepest horizontal well in the ultra-tight Rotliegendes ``Main`` sand at 15,687 ft (4,783 m) true vertical depth. The multiple frac concept provides a cost-efficient method to economically produce significant gas resources in the ultra-tight Rotliegendes ``Main`` sand. Besides the satisfactory initial gas production rate, the well established several world records, including deepest horizontal well with multiple fracs, and proved this new technique to develop ultra-tight sands.

Schueler, S. [Mobil Erdgas-Erdoel GmbH, Celle (Germany); Santos, R. [Mobil Erdgas-Erdoel GmbH, Hamburg (Germany)

1996-01-08T23:59:59.000Z

26

Vibratory Drilling of Oil Wells  

Science Journals Connector (OSTI)

Vibratory drilling refers to the process of drilling into rock by vibrating the drilling tool at audio?frequencies. The basic mechanism of vibratory drilling was ascertained by preliminary laboratory experimentation to consist of a series of impacts on the rock at the frequency of vibration. A fundamental study of this basic mechanism made by dropping weighted chisels on rock showed that the primary parameter which determined the rate of penetration was the mechanical power input to the rock per unit cross section of hole; the values of the vibration frequency and of other variables were of minor consequence over wide ranges. A theoretical analysis was made of the vibration of an elongated magnetostrictiontransducer capable of generating the required power level taking into account the distributed nature of the generation of vibrations. Intermediate power transducers have been built and tested and a high?power transducer for down?hole operation is under construction. [The material for this presentation is based on work carried out at the Battelle Memorial Institute under the sponsorship of Drilling Research Inc. an organization formed by a group of major companies engaged in various phases of oil production for the purpose of investigating novel methods of rock drilling.

Ralph Simon

1956-01-01T23:59:59.000Z

27

MIMO Control during Oil Well Drilling  

Science Journals Connector (OSTI)

Abstract A drilling system consists of a rotating drill string, which is placed into the well. The drill fluid is pumped through the drill string and exits through the choke valve. An important scope of the drill fluid is to maintain a certain pressure gradient along the length of the well. Well construction is a complex job in which annular pressures must be kept inside the operational window (limited by fracture and pore pressure). Monitoring bottom hole pressure to avoid fluctuations out of operational window limits is an extremely important job, in order to guarantee safe conditions during drilling. Under a conventional oil well drilling task, the pore pressure (minimum limit) and the fracture pressure (maximum limit) define mud density range and pressure operational window. During oil well drilling, several disturbances affect bottom hole pressure; for example, as the length of the well increases, the bottom hole pressure varies for growing hydrostatic pressure levels. In addition, the pipe connection procedure, performed at equal time intervals, stopping the drill rotation and mud injection, mounting a new pipe segment, restarting the drill fluid pump and rotation, causes severe fluctuations in well fluids flow, changing well pressure. Permeability and porous reservoir pressure governs native reservoir fluid well influx, affecting flow patterns inside the well and well pressure. In this work, a non linear mathematical model (gas-liquid-solid), representing an oil well drilling system, was developed, based on mass and momentum balances. Besides, for implementing classic control (PI), alternative control schemes were analyzed using mud pump flow rate, choke opening index and weight on bit as manipulated variables in order to control annulus bottomhole pressure and rate of penetration. Classic controller tuning was performed for servo and regulatory control studies, under MIMO frameworks.

Márcia Peixoto Vega; Marcela Galdino de Freitas; André Leibsohn Martins

2014-01-01T23:59:59.000Z

28

Drilling of wells with top drive unit  

SciTech Connect

Well drilling apparatus including a top drive drilling assembly having a motor driven stem adapted to be attached to the upper end of a drill string and drive it during a drilling operation, a torque wrench carried by the top drive assembly and movable upwardly and downwardly therewith and operable to break a threated connection between the drill string and the stem, and an elevator carried by and suspended from the top drive assembly and adapted to engage a section of drill pipe beneath the torque wrench in suspending relation. The torque wrench and elevator are preferably retained against rotation with the rotary element which drives the drill string, but may be movable vertically relative to that rotary element and relative to one another in a manner actuating the apparatus between various different operating conditions.

Boyadjieff, G.I.

1984-05-22T23:59:59.000Z

29

Well completion report on installation of horizontal wells for in-situ remediation tests  

SciTech Connect

A project to drill and install two horizontal vapor extraction/air-injection wells at the Savannah River Site (SRS), Aiken, South Carolina, was performed in September and October of 1988. This study was performed to test the feasibility of horizontal drilling technologies in unconsolidated sediments and to evaluate the effectiveness of in-situ air stripping of volatile organics from the ground water and unsaturated soils. A tremendous amount of knowledge was obtained during the drilling and installation of the two test wells. Factors of importance to be considered during design of another horizontal well drilling program follow. (1) Trips in and out of the borehole should be minimized to maintain hole stability. No reaming to enlarge the hole should be attempted. (2) Drilling fluid performance should be maximized by utilizing a low solids, low weight, moderate viscosity, high lubricity fluid. Interruption of drilling fluid circulation should be minimized. (3) Well materials should possess adequate flexibility to negotiate the curve. A flexible guide should be attached to the front of the well screen to guide the screen downhole. (4) Sands containing a minor amount of clay are recommended for completion targets, as better drilling control in the laterals was obtained in these sections.

Kaback, D.S.; Looney, B.B.; Corey, J.C.; Wright, L.M.

1989-08-01T23:59:59.000Z

30

Record geothermal well drilled in hot granite  

Science Journals Connector (OSTI)

Record geothermal well drilled in hot granite ... Researchers there have completed the second of two of the deepest and hottest geothermal wells ever drilled. ... It may become the energy source for a small electrical generating power station serving nearby communities in New Mexico. ...

1981-09-07T23:59:59.000Z

31

Salt Wells Geothermal Exploratory Drilling Program EA  

Open Energy Info (EERE)

Salt Wells Geothermal Exploratory Drilling Program EA Salt Wells Geothermal Exploratory Drilling Program EA (DOI-BLM-NV-C010-2009-0006-EA) Jump to: navigation, search OpenEI Reference LibraryAdd to library Web Site: Salt Wells Geothermal Exploratory Drilling Program EA (DOI-BLM-NV-C010-2009-0006-EA) Abstract No abstract available. Author Bureau of Land Management Published U.S. Department of the Interior- Bureau of Land Management, Carson City Field Office, Nevada, 09/14/2009 DOI Not Provided Check for DOI availability: http://crossref.org Online Internet link for Salt Wells Geothermal Exploratory Drilling Program EA (DOI-BLM-NV-C010-2009-0006-EA) Citation Bureau of Land Management. Salt Wells Geothermal Exploratory Drilling Program EA (DOI-BLM-NV-C010-2009-0006-EA) [Internet]. 09/14/2009. Carson City, NV. U.S. Department of the Interior- Bureau of Land Management,

32

Horizontal well improves oil recovery from polymer flood--  

SciTech Connect

Horizontal drilling associated with an injection scheme appears to be highly promising for obtaining additional oil recovery. Horizontal well CR 163H, in the Chateaurenard field is discussed. It demonstrated that a thin unconsolidated sand can be successfully drilled and cased. The productivity index (PI) of the well was much greater than vertical wells, and an unproduced oil bank was successfully intersected. On the negative side, it was necessary to pump low in a very deviated part of the well, and the drilling cost was high compared to an onshore vertical well. CR 163H was the fifth and probably most difficult horizontal well drilled by Elf Aquitaine. Located within a polymer-flood project, the target was a 7-m thick sand reservoir at a vertical depth of 590:0080 m. In this inverted seven-spot configuration with one injector in the center and six producers at a distance of 400 m, a polymer solution was injected from 1977 to 1983, followed by water injection.

Bruckert, L. (Elf Aquitaine, Boussens, (FR))

1989-12-18T23:59:59.000Z

33

Method of positioning tubing within a horizontal well  

SciTech Connect

This patent describes a method of variably and selectively positioning coil tubing in a horizontally drilled well having a generally vertical section, a curve section and a generally horizontal section. It comprises securing a generally hollow tubing guide shoe to one end of a tubing string; inserting the tubing guide shoe and a portion of the tubing string through the generally vertical section and the curve section and into a portion of the generally horizontal section; and inserting coil tubing through the tubing string.

Young, C.E.

1992-06-02T23:59:59.000Z

34

Horizontal oil well applications and oil recovery assessment. Volume 1: Success of horizontal well technology, Final report  

SciTech Connect

Horizontal technology has been applied in over 110 formations in the USA. Volume I of this study addresses the overall success of horizontal technology, especially in less-publicized formations, i.e., other than the Austin Chalk, Bakken, and Niobrara. Operators in the USA. and Canada were surveyed on a formation-by-formation basis by means of a questionnaire. Response data were received describing horizontal well projects in 58 formations in the USA. and 88 in Canada. Operators responses were analyzed for trends in technical and economic success based on lithology (clastics and carbonates) and resource type (light oil, heavy oil, and gas). The potential impact of horizontal technology on reserves was also estimated. A forecast of horizontal drilling activity over the next decade was developed.

Deskins, W.G.; McDonald, W.J.; Knoll, R.G.; Springer, S.J.

1995-03-01T23:59:59.000Z

35

Drop pressure optimization in oil well drilling  

Science Journals Connector (OSTI)

In this research work we are interested in minimizing losses existing when drilling an oil well. This would essentially improve the load losses by acting on the rheological parameters of the hydraulic and drilling mud. For this rheological tests were performed using a six-speed rotary viscometer (FANN 35). We used several rheological models to accurately describe the actual rheological behavior of drilling mud oil-based according to the Pearson's coefficient and to the standard deviation. To model the problem we established a system of equations that describe the essential to highlight purpose and various constraints that allow for achieving this goal. To solve the problem we developed a computer program that solves the obtained equations in Visual Basic language system. Hydraulic and rheological calculation was made for in situ application. This allowed us to estimate the distribution of losses in the well.

2014-01-01T23:59:59.000Z

36

Method of drilling and casing a well  

SciTech Connect

A well drilling rig having a rotary table for driving a drill string rotatively and having jacking mechanism for lowering casing into the well after drilling, with the jacking mechanism including fluid pressure actuated piston and cylinder means which may be left in the rig during drilling and which are positioned low enough in the rig to avoid interference with operation of the rotary table. The jacking mechanism also includes a structure which is adapted to be connected to the piston and cylinder means when the casing or other well pipe is to be lowered and which is actuable upwardly and downwardly and carries one of two pipe gripping units for progressively jacking the pipe downwardly by vertical reciprocation of that structure. The reciprocating structure may take the form of a beam extending between two pistons and actuable thereby, with a second beam being connected to cylinders within which the pistons are contained and being utilized to support the second gripping element. In one form of the invention, the rotary table when in use is supported by this second beam.

Boyadjieff, G.I.; Campbell, A.B.

1983-12-20T23:59:59.000Z

37

Drill pipe with helical ridge for drilling highly angulated wells  

SciTech Connect

This patent describes a method for drilling a highly angulated wellbore with a rotary rig having a drill string terminated with a bit which method employs drilling fluid. The improvement comprises: employing a length of drill pipe in the highly angulated drill string which has a helical ridge disposed thereabout, wherein the flight of the helical ridge is wound in the same direction as the rotation of the drill string such as to move drill cuttings in a direction from the bit to the surface upon rotation, and wherein the height of the helical ridge above the circumferential surface of the length of the drill pipe is 1 to 15 percent of the diameter of the drill pipe.

Finnegan, J.E.; Williams, J.G.

1991-08-27T23:59:59.000Z

38

Stability analysis of a borehole wall during horizontal directional drilling  

Science Journals Connector (OSTI)

In this paper, numerical simulation strategies are proposed and numerical analyses are performed to investigate the stability of a borehole wall during horizontal directional drilling in loose sand with an emphasis on the role of the filter cake in borehole stability. Two computational scenarios, one in the absence of a filter cake and one with the presence of a filter cake in a borehole wall, are investigated by considering both deep and shallow borehole situations. In the case where no filter cake is formed, the soil–drilling fluid interaction analysis shows that the effective pressure on soil particles will quickly decrease to zero even at a low drilling fluid pressure because of the rapid drainage of the drilling fluids into the loose sands. This conforms to the classical liquefaction criterion, indicating that static (flow) liquefaction-based soil crumbling and sloughing will occur even at a very low drilling fluid pressure if an effective filter cake is not formed. Soil’s permeability effect on pore pressure and the transition to a steady flow are also studied. In the second scenario in which a filter cake is formed, the hydraulic fracture failures around the bores are investigated, which are caused by the expansion of the yielding zones. The yield zone sizes and critical drilling fluid pressures at the moment of hydraulic fracturing failure are calculated from the finite element analyses and the closed-form solution, which is based on classical plasticity theories. The critical fluid pressures from the finite element analyses and the closed-form solutions are very close, but there is a large discrepancy between the yield zone sizes.

X. Wang; R.L. Sterling

2007-01-01T23:59:59.000Z

39

Two-phase flow in horizontal wells  

SciTech Connect

Flow in horizontal wells and two-phase flow interaction with the reservoir were investigated experimentally and theoretically. Two-phase flow behavior has been recognized as one of the most important problems in production engineering. The authors designed and constructed a new test facility suitable for acquiring data on the relationship between pressure drop and liquid holdup along the well and fluid influx from the reservoir. For the theoretical work, an initial model was proposed to describe the flow behavior in a horizontal well configuration. The model uses the inflow-performance-relationship (IPR) approach and empirical correlations or mechanistic models for wellbore hydraulics. Although good agreement was found between the model and experimental data, a new IPR apart from the extension of Darcy`s law must be investigated extensively to aid in the proper design of horizontal wells.

Ihara, Masaru [Japan National Oil Corp., Chiba (Japan); Yanai, Koji [Nippon Kokan Corp., Yokohama (Japan); Yanai, Koji

1995-11-01T23:59:59.000Z

40

Discussion of productivity of a horizontal well  

SciTech Connect

The authors of this paper has been using several of the analytical equations and numerical simulation to evaluate the productivity of horizontal wells that have near-wellbore damage. Through this evaluation, the author found that here are inconsistencies in the way the skin factor is introduced into the analytical equations. This discussion shows the corrections needed in various analytical equations to obtain consistency with numerical simulation. In the numerical simulation shown here, skin factor is simulated by assignment of a reduced permeability to nodes near the well. The author would appreciate any comments Babu and Odeh could make on this aspect of horizontal wells.

Gilman, J.R. (Marathon Oil Company (US))

1991-02-01T23:59:59.000Z

Note: This page contains sample records for the topic "horizontal wells drilling" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


41

Method and apparatus for drilling horizontal holes in geological structures from a vertical bore  

DOE Patents (OSTI)

This invention is directed to a method and apparatus for drilling horizontal holes in geological strata from a vertical position. The geological structures intended to be penetrated in this fashion are coal seams, as for in situ gasification or methane drainage, or in oil-bearing strata for increasing the flow rate from a pre-existing well. Other possible uses for this device might be for use in the leaching of uranium ore from underground deposits or for introducing horizontal channels for water and steam injections.

Summers, David A. (Rolla, MO); Barker, Clark R. (Rolla, MO); Keith, H. Dean (Rolla, MO)

1982-01-01T23:59:59.000Z

42

Oil and Gas Well Drilling | Open Energy Information  

Open Energy Info (EERE)

Not Provided Check for DOI availability: http:crossref.org Online Internet link for Oil and Gas Well Drilling Citation Jeff Tester. 2011. Oil and Gas Well Drilling. NA. NA....

43

Optimization of fractured well performance of horizontal gas wells  

E-Print Network (OSTI)

................................................24 3.4 Ideal Number of Transverse Fractures..........................................26 3.5 Constant Volume Transverse Fractures ........................................32 3.6... of a longitudinal fracture..............................................10 2.5 Example of horizontal well with longitudinal fracture performance .............11 2.6 DVS representation of transverse fractures...

Magalhaes, Fellipe Vieira

2009-06-02T23:59:59.000Z

44

KNOWLEDGE-BASED DECISION SUPPORT IN OIL WELL DRILLING  

E-Print Network (OSTI)

KNOWLEDGE-BASED DECISION SUPPORT IN OIL WELL DRILLING Combining general and case-specific knowledge of Computer and Information Science. agnar.aamodt@idi.ntnu.no Abstract: Oil well drilling is a complex process. This is followed, in section 3, by an oil well drilling scenario and an example from a problem solving session

Aamodt, Agnar

45

Applications of CBR in oil well drilling "A general overview"  

E-Print Network (OSTI)

Applications of CBR in oil well drilling "A general overview" Samad Valipour Shokouhi1,3 , Agnar successfully. Keywords: Case-based reasoning, oil well drilling 1 Introduction Case-based reasoning (CBR provide to the oil and gas drilling industry. The number of publications on the application of CBR

Aamodt, Agnar

46

Horizontal oil well applications and oil recovery assessment. Technical progress report, April--June 1994  

SciTech Connect

Thousands of horizontal wells are being drilled each year in the U.S.A. and around the world. Horizontal wells have increased oil and gas production rates 3 to 8 times those of vertical wells in many areas and have converted non-economic oil reserves to economic reserves. However, the use of horizontal technology in various formation types and applications has not always yielded anticipated success. The primary objective of this project is to examine factors affecting technical and economic success of horizontal well applications. The project`s goals will be accomplished through six tasks designed to evaluate the technical and economic success of horizontal drilling, highlight current limitations, and outline technical needs to overcome these limitations. Data describing operators` experiences throughout the domestic oil and gas industry will be gathered and organized. Canadian horizontal technology will also be documented with an emphasis on lessons the US industry can learn from Canada`s experience. MEI databases containing detailed horizontal case histories will also be used. All these data will be categorized and analyzed to assess the status of horizontal well technology and estimate the impact of horizontal wells on present and future domestic oil recovery and reserves.

McDonald, W.J.

1993-06-03T23:59:59.000Z

47

Economic viability of multiple-lateral horizontal wells  

E-Print Network (OSTI)

Horizontal wells are gaining popularity throughout the petroleum industry as a means to increase well productivity and enhance incremental economics. Horizontal wells provide greater reservoir exposure and are useful in intersecting additional pay...

Smith, Christopher Jason

2012-06-07T23:59:59.000Z

48

Costs of Crude Oil and Natural Gas Wells Drilled  

NLE Websites -- All DOE Office Websites (Extended Search)

Costs of Crude Oil and Natural Gas Wells Drilled Period: Annual Download Series History Download Series History Definitions, Sources & Notes Definitions, Sources & Notes 2002 2003...

49

Idaho Well Construction and Drilling Forms Webpage | Open Energy...  

Open Energy Info (EERE)

Forms Webpage Jump to: navigation, search OpenEI Reference LibraryAdd to library Web Site: Idaho Well Construction and Drilling Forms Webpage Author Idaho Department of...

50

Cost analysis of oil, gas, and geothermal well drilling  

Science Journals Connector (OSTI)

Abstract This paper evaluates current and historical drilling and completion costs of oil and gas wells and compares them with geothermal wells costs. As a starting point, we developed a new cost index for US onshore oil and gas wells based primarily on the API Joint Association Survey 1976–2009 data. This index describes year-to-year variations in drilling costs and allows one to express historical drilling expenditures in current year dollars. To distinguish from other cost indices we have labeled it the Cornell Energy Institute (CEI) Index. This index has nine sub-indices for different well depth intervals and has been corrected for yearly changes in drilling activity. The CEI index shows 70% higher increase in well cost between 2003 and 2008 compared to the commonly used Producer Price Index (PPI) for drilling oil and gas wells. Cost trends for various depths were found to be significantly different and explained in terms of variations of oil and gas prices, costs, and availability of major well components and services at particular locations. Multiple methods were evaluated to infer the cost-depth correlation for geothermal wells in current year dollars. In addition to analyzing reported costs of the most recently completed geothermal wells, we investigated the results of the predictive geothermal well cost model WellCost Lite. Moreover, a cost database of 146 historical geothermal wells has been assembled. The CEI index was initially used to normalize costs of these wells to current year dollars. A comparison of normalized costs of historical wells with recently drilled ones and WellCost Lite predictions shows that cost escalation rates of geothermal wells were considerably lower compared to hydrocarbon wells and that a cost index based on hydrocarbon wells is not applicable to geothermal well drilling. Besides evaluating the average well costs, this work examined economic improvements resulting from increased drilling experience. Learning curve effects related to drilling multiple similar wells within the same field were correlated.

Maciej Z. Lukawski; Brian J. Anderson; Chad Augustine; Louis E. Capuano Jr.; Koenraad F. Beckers; Bill Livesay; Jefferson W. Tester

2014-01-01T23:59:59.000Z

51

Horizontal Directional Drilling: A Green and Sustainable Technology for Site Remediation  

Science Journals Connector (OSTI)

Horizontal Directional Drilling: A Green and Sustainable Technology for Site Remediation ... Although a host of innovative technologies exist to treat contaminated soil and groundwater, constructing them in the field continues to rely on age-old, conventional methods: vertical drilling or excavation. ...

Michael D. Lubrecht; LG

2012-01-24T23:59:59.000Z

52

Horizontal oil well applications and oil recovery assessment. Technical progress report, January--March 1994  

SciTech Connect

The primary objective of this project is to examine factors affecting technical and economic success of horizontal well applications. The project`s goals will be accomplished through five tasks designed to evaluate the technical and economic success of horizontal drilling, highlight current limitations, and outline technical needs to overcome these limitations. Data describing operators` experiences throughout the domestic oil and gas industry will be gathered and organized. MEI databases containing detailed horizontal case histories will also be used. All these data will be categorized and analyzed to assess the status of horizontal well technology and estimate the impact of horizontal wells on present and future domestic oil recovery and reserves. Accomplishments for this quarter are presented.

McDonald, W.J.

1994-06-01T23:59:59.000Z

53

Hydraulic Fracturing and Horizontal Gas Well Drilling Reference List This list is in no way exhaustive. Rather, it attempts to provide a set of primary references that offer key pieces of  

E-Print Network (OSTI)

development Impact Assessment of Natural Gas Production in the New York City Water Supply Watershed (2009). NYCDEP http://home2.nyc.gov/html/dep/html/news/natural_gas_drilling.shtml Review of water related and infiltration events Short Scholarly Features Natural Gas Plays in the Marcellus Shale: Challenges & Potential

Wang, Z. Jane

54

Noise removal from measurements while drilling an oil well  

Science Journals Connector (OSTI)

Systems to acquire borehole data during the drilling of oil and gas wells make use of measurement while drilling (MWD). One feature of this system is that it is able to do real?time measuring from a borehole; therefore there has been a lot of MWD use on drilling sites in recent years. There are a few types of MWD. Mud pulse?type MWD which uses a drilling circuit fluid is superior to the rest because of its reliability accuracy of data and less disturbance of the drilling schedule. The drilling circuit fluid is raised to a high pressure by a mud pump; borehole data which are recorded by the surface measuring system are contaminated by the pumping noise. Therefore it is necessary to remove the pumping noise to get objective data. This report describes the pumping noise removal system and the method used for the telemetry system from 2000 m depth.

Kazuho Hosono; Haruki Moriyama

1996-01-01T23:59:59.000Z

55

Evaluation of target reservoirs for horizontal drilling: Lower Glen Rose Formation, South Texas  

SciTech Connect

The primary objective of this project is to test the hypothesis that a horizontally drilled borehole can increase gas production sufficiently from the Lower Glen Rose Formation to provide an economic advantage over conventional vertical drilling. Additional objectives are to conduct detailed investigations of reservoir properties and completion methods. This paper presents preliminary results of a project, co-funded by PrimeEnergy and the United States Department of Energy (DOE), to assess the economic viability of horizontal drilling in the Lower Glen Rose Formation of Maverick County, Texas. This project is part of an ongoing DOE investigation of directional drilling in the development of tight gas resources within the United States. This paper builds on data presented in Muncey (1992) with data from two vertical tests of the Lower Glen Rose Formation, both drilled in 1993, and the analysis of approximately 20 line-miles of high-resolution seismic data recorded in 1992 and 1993.

Muncey, G.; Drimal, C.E. Jr.

1993-12-31T23:59:59.000Z

56

Horizontal oil well applications and oil recovery assessment. Volume 2: Applications overview, Final report  

SciTech Connect

Horizontal technology has been applied in over 110 formations in the USA. Volume 1 of this study addresses the overall success of horizontal technology, especially in less-publicized formations, i.e., other than the Austin Chalk, Bakken, and Niobrara. Operators in the USA and Canada were surveyed on a formation-by-formation basis by means of a questionnaire. Response data were received describing horizontal well projects in 58 formations in the USA and 88 in Canada. Operators` responses were analyzed for trends in technical and economic success based on lithology (clastics and carbonates) and resource type (light oil, heavy oil, and gas). The potential impact of horizontal technology on reserves was also estimated. A forecast of horizontal drilling activity over the next decade was developed.

Deskins, W.G.; McDonald, W.J.; Knoll, R.G.; Springer, S.J.

1995-03-01T23:59:59.000Z

57

Improved Efficiency of Oil Well Drilling through Case Based Reasoning  

Science Journals Connector (OSTI)

A system that applies a method of knowledge-intensive case-based reasoning, for repair and prevention of unwanted events in the domain of offshore oil well drilling, has been developed in cooperation with an oil ...

Paal Skalle; Jostein Sveen; Agnar Aamodt

2000-01-01T23:59:59.000Z

58

Optimal Choice of Coordinates for Oil Well Drilling  

Science Journals Connector (OSTI)

Methods and algorithms for determining coordinates for drilling new wells on an admissible set are ... cases in which (1) time-changes in oil saturation can be neglected and (2) pressure and oil saturation distri...

A. V. Akhmetzyanov; V. N. Akhmetzyanov

2002-11-01T23:59:59.000Z

59

Water Wells and Drilled or Mined Shafts (Texas)  

Energy.gov (U.S. Department of Energy (DOE))

The drilling, excavation, and construction of a water well or mine shaft requires a permit from the Texas Commission on Environmental Quality (previously known as the Texas Natural Resource...

60

Case study of a horizontal well in a layered Rotliegendes gas field  

SciTech Connect

A horizontal well was drilled in the Ravenspurn North field to drain a thin gas column above the aquifer. The field has a significant variation in reservoir quality, with most of the wells requiring stimulation by hydraulic fracturing. The reservoir is formed from a stacked sequence of aeolian dune and fluvial sandstones with a wide permeability range. The horizontal well was chosen as an alternative to stimulation by hydraulic fracturing to avoid water production from the aquifer. The well was successful, flowing at higher gas rates than expected with no water production. Production, core, and production logging data were used to demonstrate greater than expected lateral heterogeneity in the field. The horizontal well was found to be appropriate for the very specific conditions found in one part of the reservoir; however, the overall development strategy of using hydraulic fracture remains the preferred technique.

Catterall, S.J.A.; Yaliz, A. (Hamilton Oil Co. Ltd., London (United Kingdom))

1995-02-01T23:59:59.000Z

Note: This page contains sample records for the topic "horizontal wells drilling" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


61

Two wells drilled from one surface bore with downhole splitter  

SciTech Connect

A downhole multiwell drilling template, called a downhole splitter, allows two wells to be drilled, cased, and completed from one well bore. After completion, each well can be produced, serviced, and worked over independently of the other. The downhole splitter was successfully field tested in Wyoming. The downhole splitter is suitable for use on offshore platforms, subsea completions, offshore exploitation and delineation wells, inland waters, and onshore in environmentally sensitive areas. It is also ideal for planned multilateral or multivertical completions. The paper describes the downholds splitter and its development, then discusses the field test: casing program, directional procedure, and results.

Collins, G. (Marathon Oil Co., Houston, TX (United States)); Bennett, R. (Baker Oil Tools, Houston, TX (United States))

1994-10-03T23:59:59.000Z

62

Optimization of Performance Qualifiers during Oil Well Drilling  

Science Journals Connector (OSTI)

Abstract An optimization analysis of the drilling process constitutes a powerful tool for operating under desired pressure levels (inside operational window) and, simultaneously, maximizing the rate of penetration, which must be harmonized with the conflicting objective of minimizing the specific energy. The drilling efficiency is improved as the rate of penetration is increased, however, there are conflicts with performance qualifiers, such as down hole tool life, footage, vibrations control, directional effectiveness and hydraulic scenarios. Concerning hydraulic effects, the minimization of the specific energy must be constrained by annulus bottom hole pressure safe region, using the operational window, placed above porous pressure and below fracture pressure. Under a conventional oil well drilling task, the pore pressure (minimum limit) and the fracture pressure (maximum limit) define mud density range and pressure operational window. During oil well drilling, several disturbances affect bottom hole pressure; for example, as the length of the well increases, the bottom hole pressure varies for growing hydrostatic pressure levels. In addition, the pipe connection procedure, performed at equal time intervals, stopping the drill rotation and mud injection, mounting a new pipe segment, restarting the drill fluid pump and rotation, causes severe fluctuations in well fluids flow, changing well pressure. Permeability and porous reservoir pressure governs native reservoir fluid well influx, affecting flow patterns inside the well and well pressure. The objective being tracked is operating under desired pressure levels, which assures process safety, also reducing costs. In this scenario, optimization techniques are important tools for narrow operational windows, commonly observed at deepwater and pre-salt layer environments. The major objective of this paper is developing an optimization methodology for minimizing the specific energy, also assuring safe operation (inside operational window), despite the inherent process disturbances, under a scenario that maximization of ROP (rate of penetration) is a target.

Márcia Peixoto Vega; Marcela Galdino de Freitas; André Leibsohn Martins

2014-01-01T23:59:59.000Z

63

Proper planning improves flow drilling  

SciTech Connect

Underbalanced operations reduce formation damage, especially in horizontal wells where zones are exposed to mud for longer time periods. Benefits, risks, well control concerns, equipment and issues associated with these operations are addressed in this paper. Flow drilling raises many concerns, but little has been published on horizontal well control and flow drilling operations. This article covers planning considerations for flow drilling, but does not address horizontal ''overbalanced'' drilling because considerations and equipment are the same as in vertical overbalanced drilling and many references address that subject. The difference in well control between vertical and horizontal overbalanced drilling is fluid influx behavior and how that behavior affects kill operations.

Collins, G.J. (Marathon Oil Co., Houston, TX (United States))

1994-10-01T23:59:59.000Z

64

Productivity and Injectivity of Horizontal Wells  

SciTech Connect

A general wellbore flow model is presented to incorporate not only frictional, accelerational and gravitational pressure drops, but also the pressure drop caused by inflow. Influence of inflow or outflow on the wellbore pressure drop is analyzed. New friction factor correlations accounting for both inflow and outflow are also developed. The greatest source of uncertainty is reservoir description and how it is used in simulators. Integration of data through geostatistical techniques leads to multiple descriptions that all honor available data. The reality is never known. The only way to reduce this uncertainty is to use more data from geological studies, formation evaluation, high resolution seismic, well tests and production history to constrain stochastic images. Even with a perfect knowledge about reservoir geology, current models cannot do routine simulations at a fine enough scale. Furthermore, we normally don't know what scale is fine enough. Upscaling introduces errors and masks some of the physical phenomenon that we are trying to model. The scale at which upscaling is robust is not known and it is probably smaller in most cases than the scale actually used for predicting performance. Uncertainties in the well index can cause errors in predictions that are of the same magnitude as those caused by reservoir heterogeneities. Simplified semi-analytical models for cresting behavior and productivity predictions can be very misleading.

Khalid Aziz; Sepehr Arababi; Thomas A. Hewett

1997-04-29T23:59:59.000Z

65

Laser Oil and Gas Well Drilling Demonstration Videos  

DOE Data Explorer (OSTI)

ANL's Laser Applications Laboratory and collaborators are examining the feasibility of adapting high-power laser technology to drilling for gas and oil. The initial phase is designed to establish a scientific basis for developing a commercial laser drilling system and determine the level of gas industry interest in pursuing future research. Using lasers to bore a hole offers an entirely new approach to mechanical drilling. The novel drilling system would transfer light energy from lasers on the surface, down a borehole by a fiber optic bundle, to a series of lenses that would direct the laser light to the rock face. Researchers believe that state-of-the-art lasers have the potential to penetrate rock many times faster than conventional boring technologies - a huge benefit in reducing the high costs of operating a drill rig. Because the laser head does not contact the rock, there is no need to stop drilling to replace a mechanical bit. Moreover, researchers believe that lasers have the ability to melt the rock in a way that creates a ceramic sheath in the wellbore, eliminating the expense of buying and setting steel well casing. A laser system could also contain a variety of downhole sensors, including visual imaging systems that could communicate with the surface through the fiber optic cabling. Earlier studies have been promising, but there is still much to learn. One of the primary objectives of the new study will be to obtain much more precise measurements of the energy requirements needed to transmit light from surface lasers down a borehole with enough power to bore through rocks as much as 20,000 feet or more below the surface. Another objective will be to determine if sending the laser light in sharp pulses, rather than as a continuous stream, could further increase the rate of rock penetration. A third aspect will be to determine if lasers can be used in the presence of drilling fluids. In most wells, thick fluids called "drilling muds" are injected into the borehole to wash out rock cuttings and keep water and other fluids from the underground formations from seeping into the well. The technical challenge will be to determine whether too much laser energy is expended to clear away the fluid where the drilling is occurring. (Copied with editing from http://www.ne.anl.gov/facilities/lal/laser_drilling.html). The demonstration videos, provided here in QuickTime format, are accompanied by patent documents and PDF reports that, together, provide an overall picture of this fascinating project.

66

Simulation studies of waterflood performance with horizontal wells  

E-Print Network (OSTI)

Two-and three-dimensional simulation studies have been carried out to evaluate waterflood oil recovery in a 40-acre 5-spot pattern using horizontal and vertical well systems. The three-dimensional simulation results indicate that the parameters...

Ferreira, Horacio

1995-01-01T23:59:59.000Z

67

A Triple-Porosity Model for Fractured Horizontal Wells  

E-Print Network (OSTI)

A TRIPLE-POROSITY MODEL FOR FRACTURED HORIZONTAL WELLS A Thesis by HASAN ALI H ALAHMADI Submitted to the Office of Graduate Studies of Texas A&M University in partial fulfillment of the requirements for the degree of MASTER... OF SCIENCE August 2010 Major Subject: Petroleum Engineering A Triple-Porosity Model for Fractured Horizontal Wells Copyright 2010 Hasan Ali H Alahmadi A TRIPLE-POROSITY MODEL FOR FRACTURED...

Alahmadi, Hasan Ali H.

2010-10-12T23:59:59.000Z

68

An integrated approach to evaluation of horizontal well prospects in the Niobrara Shale  

SciTech Connect

Integrated use of surface and subsurface geologic data, structural deformation analysis from second-derivative maps, and dimensionless type curves in identifying potential horizontal well locations in the fractured Niobrara Shale of northwest Colorado is described. The analysis included construction of detailed structure maps from surface geology with tie-ins to seismic surveys and well control and of second-derivative maps that were overlaid on production data to determine the minimum radius of curvature required for commercial production. Reservoir properties were calculated for known fields from type-curve matching with type curves for dual-porosity, anisotropic reservoirs with stress-sensitive permeability. The curves were constructed for vertical and horizontal wells by use of reservoir-simulation models. Spacing and economics of drilling horizontal Niobrara wells in northwest Colorado were evaluated. The analysis suggests that recoverable oil from the fractured Niobrara in northwest Colorado averages 1,392 bbl oil/acre on the basis of a productive fracture area identified by second derivatives of the structural surface with values > 1{times}10{sup {minus}4.5}ft{sup {minus}1}. It is also indicated that horizontal well spacing in the fractured Niobrara should be >640 acres. In some instances, it may be more economical to develop the fractured Niobrara with vertical rather than horizontal wells.

Stright, D.H. Jr. [Simtech Consulting Services Inc., Golden, CO (United States); Robertson, R.D. [Cabot Oil and Gas, Denver, CO (United States)

1995-11-01T23:59:59.000Z

69

Chapter 13 - Plugging In-Mine Boreholes and CBM Wells Drilled from Surface  

Science Journals Connector (OSTI)

Abstract Horizontal degasification boreholes drilled from within the mine or from the surface have proven to be effective in recovering coalbed methane (CBM) for degasification and commercial marketing. However, the inability to completely plug horizontal boreholes still producing gas prior to mine through has caused unsafe situations and significant coal production delays. To date, cement slurry has commonly been used to plug underground horizontal degasification boreholes CBM wells, including sidetracks. Over 546,000 gallons of cross-linked polymer gel has been pumped to seal these 80 boreholes. The quantity of gel pumped is almost two times the calculated volume of the boreholes, including sidetracks. The gel effectively flows into the fracture system of the coal displacing gas and water. Finally, with an affinity to attach itself to everything, except for itself, the gel adhered to the inner wall of the borehole providing an impenetrable skin, minimizing gas, and water migrating back into the borehole as evidenced by mining into the boreholes.

Gary DuBois; Stephen Kravits; Joe Kirley; Doug Conklin; Joanne Reilly

2014-01-01T23:59:59.000Z

70

Tests show production logging problems in horizontal gas wells  

SciTech Connect

A study has concluded that production logging tools employed to evaluate multiphase horizontal well production behavior should be carefully screened as to their response characteristics in fully-segregated, two-phase flow. The study, performed at Marathon Oil Co.'s petroleum technology center in Littleton, Colo., indicated that gas in highly deviated well bores segregates rapidly in the presence of water, creating a downhole environment that produces sporadic responses from full bore and diverter spinners as well as density and holdup tools. Gas Research Institute (GRI), as part of its horizontal gas well completion technology program, initiated the full-scale laboratory study to determine the severity and consequences of multiphase flow on tool response from horizontal well production. The paper discusses background of the problem, the test objectives, test facility, experimental procedures, single-phase flow, two-phase flow, and recommendations.

Branagan, P. (Branagan and Associates, Las Vegas, NV (United States)); Knight, B.L. (Marathon Oil Co., Littleton, CO (United States)); Aslakson, J. (Gas Research Inst., Chicago, IL (United States)); Middlebrook, M.L. (CER Corp., Las Vegas, NV (United States))

1994-01-10T23:59:59.000Z

71

Integrated approach towards the application of horizontal wells to improve waterflooding performance. Annual report  

SciTech Connect

This annual report describes the progress during the second year of the project on Integrated Approach Towards the Application of Horizontal Wells to Improve Waterflooding Performance. This project is funded under the Department of Energy`s Class I program which is targeted towards improving the reservoir performance of mature oil fields located in fluvial-dominated deltaic deposits. The project involves an integrated approach to characterize the reservoir followed by the drilling of horizontal injection wells to improve production performance. The type of data we have integrated include cross bore hole seismic surveys, geological interpretation based on logs and cores, and engineering information. This report covers the second phase of the project which includes a detailed reservoir description of the field by integrating all the available information, followed by flow simulation of the Self Unit under various operating conditions. Based on an examination of the various operating parameters, we observed that the best possible solution to improve the Self Unit performance is to recomplete and stimulate most of the wells followed by an increase in the water injection rate. Drilling of horizontal injection well, although helpful in improving the performance, was not found to be economically feasible. The proposed reservoir management plan will be implemented shortly.

Kelkar, M.; Liner, C.; Kerr, D.

1995-05-01T23:59:59.000Z

72

Multi-objective optimization of oil well drilling using elitist non-dominated sorting genetic algorithm  

Science Journals Connector (OSTI)

A multi-objective optimization of oil well drilling has been carried out using a binary ... functions were formulated and solved to fix optimal drilling variables. The important objectives are: (i) maximizing drilling

Chandan Guria; Kiran K. Goli; Akhilendra K. Pathak

2014-03-01T23:59:59.000Z

73

U.S. Nominal Cost per Dry Well Drilled (Thousand Dollars per...  

Annual Energy Outlook 2012 (EIA)

Dry Well Drilled (Thousand Dollars per Well) U.S. Nominal Cost per Dry Well Drilled (Thousand Dollars per Well) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7...

74

U.S. Nominal Cost per Natural Gas Well Drilled (Thousand Dollars...  

Annual Energy Outlook 2012 (EIA)

Natural Gas Well Drilled (Thousand Dollars per Well) U.S. Nominal Cost per Natural Gas Well Drilled (Thousand Dollars per Well) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5...

75

U.S. Real Cost per Crude Oil, Natural Gas, and Dry Well Drilled...  

Annual Energy Outlook 2012 (EIA)

Crude Oil, Natural Gas, and Dry Well Drilled (Thousand Dollars per Well) U.S. Real Cost per Crude Oil, Natural Gas, and Dry Well Drilled (Thousand Dollars per Well) Decade Year-0...

76

U.S. Nominal Cost per Crude Oil Well Drilled (Thousand Dollars...  

Annual Energy Outlook 2012 (EIA)

Oil Well Drilled (Thousand Dollars per Well) U.S. Nominal Cost per Crude Oil Well Drilled (Thousand Dollars per Well) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7...

77

U.S. Nominal Cost per Crude Oil, Natural Gas, and Dry Well Drilled...  

Gasoline and Diesel Fuel Update (EIA)

Oil, Natural Gas, and Dry Well Drilled (Thousand Dollars per Well) U.S. Nominal Cost per Crude Oil, Natural Gas, and Dry Well Drilled (Thousand Dollars per Well) Decade Year-0...

78

U.S. Average Depth of Natural Gas Developmental Wells Drilled...  

Annual Energy Outlook 2012 (EIA)

Developmental Wells Drilled (Feet per Well) U.S. Average Depth of Natural Gas Developmental Wells Drilled (Feet per Well) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6...

79

U.S. Average Depth of Natural Gas Exploratory Wells Drilled ...  

Annual Energy Outlook 2012 (EIA)

Wells Drilled (Feet per Well) U.S. Average Depth of Natural Gas Exploratory Wells Drilled (Feet per Well) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8...

80

Integrated Approach Towards the Application of Horizontal Wells to Improve Waterflooding Performance  

SciTech Connect

This final report describes the progress during the six year of the project on ''Integrated Approach Towards the Application of Horizontal Wells to Improve Waterflooding Performance.'' This report is funded under the Department of Energy's (DOE's) Class I program which is targeted towards improving the reservoir performance of mature oil fields located in fluvially-dominated deltaic deposits. The project involves using an integrated approach to characterize the reservoir followed by drilling of horizontal injection wells to improve production performance. The project was divided into two budget periods. In the first budget period, many modern technologies were used to develop a detailed reservoir management plan; whereas, in the second budget period, conventional data was used to develop a reservoir management plan. The idea was to determine the cost effectiveness of various technologies in improving the performance of mature oil fields.

Kelkar, Mohan; Liner, Chris; Kerr, Dennis

1999-10-15T23:59:59.000Z

Note: This page contains sample records for the topic "horizontal wells drilling" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


81

WATERJETTING: A NEW DRILLING TECHNIQUE IN COALBED METHANE RESERVOIRS.  

E-Print Network (OSTI)

??WATERJETTING: A NEW DRILLING TECHNIQUE IN COALBED METHANE RESERVOIRS Applications of waterjeting to drill horizontal wells for the purpose of degassing coalbeds prior to mining… (more)

Funmilayo, Gbenga M.

2010-01-01T23:59:59.000Z

82

Using borehole images for target-zone evaluation in horizontal wells  

SciTech Connect

Horizontal wells are rarely horizontal. Instead, operators commonly try to drill such wells into particular rock layers, or target zones, which may or may not be truly horizontal. Thicknesses of target zones commonly range from a few feet to a few tens of feet (1-10 m). Target-zone evaluation concerns whether a horizontal well was successfully located and drilled in a given rock layer. Borehole-imaging logs provide a powerful tool for stratigraphic interpretation and target-zone evaluation in the Austin Chalk, Niobrara Formation, San Andres Formation, and other units. This study uses borehole images generated by Schlumberger's Formation MicroScanner (FMS), a microconductivity logging device. Open fractures and clay-rich interbeds appear as dark, high-conductivity tracers on the FMS log. These traces can be fit with sinusoidal curves and oriented on a computer workstation. The shape of the sinusoidal curve that fits a particular bedding plane tells the interpreter whether the borehole was moving upward or downward through the strata. STRATLOG (trademark of Sierra Geophysics, Inc., a Halliburton Company) software has been used to display borehole profiles by combining FMS data on fracture intensities and bedding-plane intersections with gamma-ray logs, mud logs, and borehole-deviation surveys. To aid in planning future wells, multiple penetrations of the same horizon can be detected and used to calculate highly accurate bedding-plane dips. Fault interpretation, including the detection of rollover beds, it also possible. Finally, stratigraphic interpretation can be combined with observed fractures to determine which rock layers are most highly fractured, and, therefore, should be target zones.9 refs., 5 figs.

Hurley, N.F.; Carlson, J.L. (Marathon Oil Company, Littleton, CO (United States)); Thorn, D.R. (Schlumberger Well Services, Aurora (Colombia)); Eichelberger, L.W. (Marathon Oil Company, Tyler, TX (United States))

1994-02-01T23:59:59.000Z

83

Footage Drilled for Crude Oil and Natural Gas Wells  

Gasoline and Diesel Fuel Update (EIA)

Footage Drilled for Crude Oil and Natural Gas Wells Footage Drilled for Crude Oil and Natural Gas Wells (Thousand Feet) Period: Annual Download Series History Download Series History Definitions, Sources & Notes Definitions, Sources & Notes 2003 2004 2005 2006 2007 2008 View History Exploratory and Development Wells 176,867 203,997 240,969 285,398 308,210 331,740 1949-2008 Crude Oil 38,495 42,032 51,511 63,649 66,527 88,382 1949-2008 Natural Gas 115,833 138,503 164,353 193,595 212,753 212,079 1949-2008 Dry Holes 22,539 23,462 25,104 28,154 28,931 31,280 1949-2008 Exploratory Wells 17,785 22,382 25,955 29,630 36,534 35,585 1949-2008 Crude Oil 2,453 3,141 4,262 4,998 6,271 7,389 1949-2008 Natural Gas 6,569 9,998 12,347 14,945 19,982 17,066 1949-2008 Dry Holes

84

Costs of Crude Oil and Natural Gas Wells Drilled  

Gasoline and Diesel Fuel Update (EIA)

Costs of Crude Oil and Natural Gas Wells Drilled Costs of Crude Oil and Natural Gas Wells Drilled Period: Annual Download Series History Download Series History Definitions, Sources & Notes Definitions, Sources & Notes 2002 2003 2004 2005 2006 2007 View History Thousand Dollars per Well All (Real*) 1,011.9 1,127.4 1,528.5 1,522.3 1,801.3 3,481.8 1960-2007 All (Nominal) 1,054.2 1,199.5 1,673.1 1,720.7 2,101.7 4,171.7 1960-2007 Crude Oil (Nominal) 882.8 1,037.3 1,441.8 1,920.4 2,238.6 4,000.4 1960-2007 Natural Gas (Nominal) 991.9 1,106.0 1,716.4 1,497.6 1,936.2 3,906.9 1960-2007 Dry Holes (Nominal) 1,673.4 2,065.1 1,977.3 2,392.9 2,664.6 6,131.2 1960-2007 Dollars per Foot All (Real*) 187.46 203.25 267.28 271.16 324.00 574.46 1960-2007 All (Nominal) 195.31 216.27 292.57 306.50 378.03 688.30 1960-2007

85

U.S. Nominal Cost per Foot of Natural Gas Wells Drilled (Dollars...  

Annual Energy Outlook 2012 (EIA)

Natural Gas Wells Drilled (Dollars per Foot) U.S. Nominal Cost per Foot of Natural Gas Wells Drilled (Dollars per Foot) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6...

86

U.S. Nominal Cost per Foot of Crude Oil Wells Drilled (Dollars...  

Annual Energy Outlook 2012 (EIA)

Oil Wells Drilled (Dollars per Foot) U.S. Nominal Cost per Foot of Crude Oil Wells Drilled (Dollars per Foot) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8...

87

Comparative Experiments with GRASP and Constraint Programming for the Oil Well Drilling Problem  

Science Journals Connector (OSTI)

Before promising locations become productive oil wells, it is often necessary to complete drilling activities at these locations. The scheduling of ... Search Procedure (GRASP) for the scheduling of oil well drilling

Romulo A. Pereira; Arnaldo V. Moura…

2005-01-01T23:59:59.000Z

88

Surface control bent sub for directional drilling of petroleum wells  

DOE Patents (OSTI)

Directional drilling apparatus for incorporation in a drill string, wherein a lower apparatus section is angularly deviated from vertical by cam action and wherein rotational displacement of the angularly deviated apparatus section is overcome by additional cam action, the apparatus being operated by successive increases and decreases of internal drill string pressure.

Russell, Larry R. (6025 Edgemoor, Suite C, Houston, TX 77081)

1986-01-01T23:59:59.000Z

89

Adaptive Observer Design under Low Data Rate Transmission with Applications to Oil Well Drill-string  

E-Print Network (OSTI)

Adaptive Observer Design under Low Data Rate Transmission with Applications to Oil Well Drill system. Index Terms-- Stick-Slip, Oil Well drill string, D-OSKIL, unknown parameter adaptive observer, time-variant, delay, stability. I. INTRODUCTION Oil well drilling operations present a particular

Paris-Sud XI, Université de

90

A SEMI-AUTOMATIC METHOD FOR CASE ACQUISITION IN CBR A STUDY IN OIL WELL DRILLING  

E-Print Network (OSTI)

A SEMI-AUTOMATIC METHOD FOR CASE ACQUISITION IN CBR A STUDY IN OIL WELL DRILLING Samad Valipour, Norway valipour@ntnu.no, agnar.aamodt@idi.ntnu.no, pal.skalle@ntnu.no ABSTRACT Oil well drilling and re-using previous experiences. KEY WORDS Case-based reasoning, oil well drilling, knowledge discovery

Aamodt, Agnar

91

Heterogeneous Shallow-Shelf Carbonate Buildups in the Paradox Basin, Utah and Colorado: Targets for Increased Oil Production and Reserves Using Horizontal Drilling Techniques  

SciTech Connect

The primary objective of this project was to enhance domestic petroleum production by demonstration and transfer of horizontal drilling technology in the Paradox basin, Utah, Colorado, Arizona, and New Mexico. If this project can demonstrate technical and economic feasibility, then the technique can be applied to approximately 100 additional small fields in the Paradox basin alone, and result in increased recovery of 25 to 50 million barrels (40-80 million m3) of oil. This project was designed to characterize several shallow-shelf carbonate reservoirs in the Pennsylvania (Desmoinesian) Paradox Formation, choose the best candidate(s) for a pilot demonstration project to drill horizontally from existing vertical wells, monitor well performances, and report associated validation activities.

Chidsey, Thomas C. Jr.; Eby, David E.; Wray, Laura L.

2001-04-19T23:59:59.000Z

92

Heterogeneous Shallow-Shelf Carbonate Buildups in the Paradox Basin, Utah and Colorado: Targets for Increased Oil Production and Reserves Using Horizontal Drilling Techniques  

SciTech Connect

The project's primary objective was to enhance domestic petroleum production by demonstration and transfer of horizontal drilling technology in the Paradox Basin, Utah, Colorado, Arizona, and New Mexico. If this project can demonstrate technical and economic feasibility, then the technique can be applied to approximately 100 additional small fields in the Paradox Basin alone, and result in increased recovery of 25 to 50 million barrels (4-8 million m3) of oil. This project was designed to characterize several shallow-shelf carbonate reservoirs in the Pennsylvanian (Desmoinesian) Paradox Formation, choose the best candidate(s) for a pilot demonstration project to drill horizontally from existing vertical wells, monitor well performance(s), and report associated validation activities.

Chidsey, Jr., Thomas C.; Eby, David E.; Wray, Laural L.

2001-11-26T23:59:59.000Z

93

A Real-Time Decision Support System for High Cost Oil-Well Drilling Operations  

E-Print Network (OSTI)

A Real-Time Decision Support System for High Cost Oil-Well Drilling Operations Odd Erik Gundersen In this paper we present DrillEdge - a commercial and award winning software system that monitors oil that provides real-time deci- sion support when drilling oil wells. Decisions are supported through analyzing

Aamodt, Agnar

94

Motor Drives of Modern Drilling and Servicing Rigs for Oil and Gas Wells  

Science Journals Connector (OSTI)

This paper provides a synthetic view on the most recent achievements in the field of drilling and servicing rig drives for oil and gas wells. This field is featuring ... kilowatts and speeds of 150–250 rpm for drilling

Aurelian Iamandei; Gheorghe Miloiu

2013-01-01T23:59:59.000Z

95

Bailer for top head drive rotary well drills  

SciTech Connect

A bailer mounted to the derrick of a top head drive well drilling rig is described. The bailer includes a winch line drum mounted by a bracket to the derrick. A positive displacement hydraulic motor mounts one end of the drum and receives fluid under pressure from the existing hydraulic pressure supply. Valving is provided to allow reverse operation of the motor so equipment can either be raised or lowered relative to the derrick. The hydraulic delivery line to the motor includes a one way restrictor that will allow relatively free passage of fluid to the motor in a driving or lifting mode but will reverse flow of fluid from the motor, thereby affording a braking effect for lowering a load at a selected rate.

Bartholomew, L.

1980-09-23T23:59:59.000Z

96

Fracturing pressures and near-well fracture geometry of arbitrarily oriented and horizontal wells  

SciTech Connect

The hydraulic fracturing of arbitrarily oriented and horizontal wells is made challenging by the far more complicated near-well fracture geometry compared to that of conventional vertical wells. This geometry is important both for hydraulic fracture propagation and the subsequent post-treatment well performance. Fracture tortuosity of arbitrarily oriented and horizontal wells is likely to cause large initiation pressures and reduction in the fracture widths. This paper presents a comprehensive study of the effects of important variables, including the principal stresses, wellbore orientation, and perforation configuration on fracture geometry. Initiation pressures, the contact between arbitrarily oriented wells and the fracture plane, and the near-well fracture geometry are determined and discussed. This study also shows that because of the near-well stress concentration the fracture width at the wellbore is always smaller than the maximum fracture width. This can have important consequences during hydraulic fracturing.

Chen, Z.; Economides, M.J.

1995-12-31T23:59:59.000Z

97

Horizontal well will be employed in hydraulic fracturing research  

SciTech Connect

This paper reports on 10-well research site, planned to enable more controlled experiments for better definition of hydraulic fracturing. One of the 10 wells will be a near-horizontal well that will monitor microseismic events along its length. The Gas Research Institute (GR) has begun evaluating a low-permeability, gas-bearing sandstone as the target stratum for experiments to be conducted at its hydraulic fracture test site (HFTS). During a 4-year period, GRI will use the HFTS as a field laboratory to conduct multi-disciplinary research projects to assess the mechanics of hydraulic fracturing. As a result of a screening process the Davis sandstone in the Ft. Worth basin has emerged as the tight gas sand which best fits the selected criteria established by GRI and its contractors, GRI says. The Ft. Worth basin is located approximately 50 miles northwest of Ft. Worth. GRI is planning a research well to fully characterize the Davis prior to making a final decision on the location of the HFTS. If data from the research well indicate the Davis sand does not adequately meet selection criteria, other candidates identified in the screening process will be investigated.

Not Available

1991-05-20T23:59:59.000Z

98

Zero Discharge Water Management for Horizontal Shale Gas Well Development  

NLE Websites -- All DOE Office Websites (Extended Search)

Discharge Water Management for Discharge Water Management for Horizontal Shale Gas Well Development Final Report Start Date: October 1, 2009 End Date: March 31, 2012 Authors: Paul Ziemkiewicz, PhD Jennifer Hause Raymond Lovett, PhD David Locke Harry Johnson Doug Patchen, PG Report Date Issued: June 2012 DOE Award #: DE-FE0001466 Submitting Organization: West Virginia Water Research Institute West Virginia University PO Box 6064 Morgantown, WV 26506-6064 FilterSure, Inc. PO Box 1277 McLean, VA 22101 ShipShaper, LLP PO Box 2 Morgantown, WV 26507 2 | P a g e Acknowledgment "This material is based upon work supported by the Department of Energy under Award Number DE-FE0001466." Disclaimer "This report was prepared as an account of work sponsored by an agency of the United States

99

Studying rheological behavior of nanoclay as oil well drilling fluid  

Science Journals Connector (OSTI)

Bentonite is commonly used to control the rheology and filtrate loss required for water-based drilling fluids. In this study, the effect ... modification on fluid viscosity and its dispersion in oil-wet fluids we...

M. Mohammadi; M. Kouhi; A. Sarrafi; M. Schaffie

2013-09-01T23:59:59.000Z

100

Simulation of air and mist drilling for geothermal wells  

SciTech Connect

An improved method for calculating downhole temperatures, pressures, fluid densities and velocities during air drilling has been developed. The basic equations of fluid flow for a gas with cuttings and mist are presented along with a numerical method for their solution. Several applications of this calculational method are given, showing the effect of flow rate and standpipe pressures in typical air and mist drilling situations. 8 refs.

Mitchell, R.F.

1981-01-01T23:59:59.000Z

Note: This page contains sample records for the topic "horizontal wells drilling" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


101

Rotary torque and rpm indicator for oil well drilling rigs  

SciTech Connect

Monitoring the torque applied by the rotary table to the drill string and the rpm of the drill string is provided. An intermediate adapter is positioned between the drill kelly and the rotary table. A strain gauge is attached to the intermediate adapter to measure torsional deformation and provide an indication of rotary torque. Transmission of torque data is accomplished by radio frequency transmission utilizing a transmitter on the intermediate adapter. A receiver is mounted to the side of the drill rig floor to receive and demodulate the torque signal. The intermediate adapter is rotating at the same rate as the drill string. Detection of the revolutions utilizing the changing R.F. Field strength is accomplished at the edge of the drill rig platform or elsewhere with a stationary sensor which doubles as the torque receiver. A highly directional torque transmitter antenna mounted on the adapter is used with the major lobe lying parallel to the rig floor and perpendicular to the pipe. By detecting the envelope of the radio frequency field strength, each rotation is marked by a peak. This enables continuous torque and rpm monitoring.

Chien, L.C.

1981-08-25T23:59:59.000Z

102

Kick circulation analysis for extended reach and horizontal wells  

E-Print Network (OSTI)

loop to study gas removal in horizontal wellbores with an inclination greater than horizontal. His test setup consisted of outer pipe with an inner diameter of 6.37 in. and inner pipe with an outer diameter of 2.37 in. As gas and liquid were flowed... loop to study gas removal in horizontal wellbores with an inclination greater than horizontal. His test setup consisted of outer pipe with an inner diameter of 6.37 in. and inner pipe with an outer diameter of 2.37 in. As gas and liquid were flowed...

Long, Maximilian Mark

2005-02-17T23:59:59.000Z

103

Use of Cutting-Edge Horizontal and Underbalanced Drilling Technologies and Subsurface Seismic Techniques to Explore, Drill and Produce Reservoired Oil and Gas from the Fractured Monterey Below 10,000 ft in the Santa Maria Basin of California  

SciTech Connect

This project was undertaken to demonstrate that oil and gas can be drilled and produced safely and economically from a fractured Monterey reservoir in the Santa Maria Basin of California by employing horizontal wellbores and underbalanced drilling technologies. Two vertical wells were previously drilled in this area with heavy mud and conventional completions; neither was commercially productive. A new well was drilled by the project team in 2004 with the objective of accessing an extended length of oil-bearing, high-resistivity Monterey shale via a horizontal wellbore, while implementing managed-pressure drilling (MPD) techniques to avoid formation damage. Initial project meetings were conducted in October 2003. The team confirmed that the demonstration well would be completed open-hole to minimize productivity impairment. Following an overview of the geologic setting and local field experience, critical aspects of the application were identified. At the pre-spud meeting in January 2004, the final well design was confirmed and the well programming/service company requirements assigned. Various design elements were reduced in scope due to significant budgetary constraints. Major alterations to the original plan included: (1) a VSP seismic survey was delayed to a later phase; (2) a new (larger) surface hole would be drilled rather than re-enter an existing well; (3) a 7-in. liner would be placed into the top of the Monterey target as quickly as possible to avoid problems with hole stability; (4) evaluation activities were reduced in scope; (5) geosteering observations for fracture access would be deduced from penetration rate, cuttings description and hydrocarbon in-flow; and (6) rather than use nitrogen, a novel air-injection MPD system was to be implemented. Drilling operations, delayed from the original schedule by capital constraints and lack of rig availability, were conducted from September 12 to November 11, 2004. The vertical and upper curved sections were drilled and lined through the problematic shale member without major stability problems. The top of the targeted Monterey was thought to be seen at the expected TVD of 10,000 ft where the 7-in. liner was set at a 60{sup o} hole angle. Significant oil and gas shows suggested the fractured interval anticipated at the heel location had been penetrated. A total of 2572 ft of 6{Delta}-in. near-horizontal interval was placed in the shale section, extending planned well length by approximately 470 ft. Very little hydrocarbon in-flow was observed from fractures along the productive interval. This may be a result of the well trajectory falling underneath the Monterey fractured zone. Hydrocarbon observations, cuttings analysis and gamma-ray response indicated additional fractured intervals were accessed along the last {+-}900 ft of well length. The well was completed with a 2 and 7/8-in. tubing string set in a production packer in preparation for flow and swab tests to be conducted later by a service rig. The planned well time was estimated as 39 days and overall cost as $2.4 million. The actual results are 66 days at a total cost of $3.4 million. Well productivity responses during subsequent flow and swabbing tests were negative. The well failed to inflow and only minor amounts (a few barrels) of light oil were recovered. The lack of production may suggest that actual sustainable reservoir pressure is far less than anticipated. Temblor attempted in July, 2006, to re-enter and clean out the well and run an Array Induction log (primarily for resistivity and correlation purposes), and an FMI log (for fracture detection). Application of surfactant in the length of the horizontal hole, and acid over the fracture zone at 10,236 was also planned. This attempt was not successful in that the clean out tools became stuck and had to be abandoned.

George Witter; Robert Knoll; William Rehm; Thomas Williams

2006-06-30T23:59:59.000Z

104

A review of light amplification by stimulated emission of radiation in oil and gas well drilling  

Science Journals Connector (OSTI)

Abstract The prospect of employing Light Amplification by Stimulated Emission of Radiation (LASER) for well drilling in oil and gas industry was examined. In this work, the experimental works carried out on various oil well drilling operations was discussed. The results show that, LASER or LASER-aided oil and gas well drilling has many potential advantages over conventional rotary drilling, including high penetration rate, reduction or elimination of tripping, casing, bit costs, enhanced well control, as well as perforating and side-tracking capabilities. The investigation also reveals that modern infrared \\{LASERs\\} have a higher rate of rock cuttings removal than that of conventional rotary drilling and flame-jet spallation. It also reveals that LASER can destroy rock without damaging formation permeability but rather, it enhances or improves permeability and that permeability and porosity increases in all rock types. The paper has therefore provided more knowledge on the potential value to drilling operations and techniques using LASER.

M OLALEYE B

2010-01-01T23:59:59.000Z

105

Use of Cutting-Edge Horizontal and Underbalanced Drilling Technologies and Subsurface Seismic Techniques to Explore, Drill and Produce Reservoired Oil and Gas from the Fractured Monterey Below 10,000 ft in the Santa Maria Basin of California  

SciTech Connect

This project was undertaken to demonstrate that oil and gas can be drilled and produced safely and economically from a fractured Monterey reservoir in the Santa Maria Basin of California by employing horizontal wellbores and underbalanced drilling technologies. Two vertical wells were previously drilled in this area with heavy mud and conventional completions; neither was commercially productive. A new well was drilled by the project team in 2004 with the objective of accessing an extended length of oil-bearing, high-resistivity Monterey shale via a horizontal wellbore, while implementing managed-pressure drilling (MPD) techniques to avoid formation damage. Initial project meetings were conducted in October 2003. The team confirmed that the demonstration well would be completed open-hole to minimize productivity impairment. Following an overview of the geologic setting and local field experience, critical aspects of the application were identified. At the pre-spud meeting in January 2004, the final well design was confirmed and the well programming/service company requirements assigned. Various design elements were reduced in scope due to significant budgetary constraints. Major alterations to the original plan included: (1) a VSP seismic survey was delayed to a later phase; (2) a new (larger) surface hole would be drilled rather than re-enter an existing well; (3) a 7-in. liner would be placed into the top of the Monterey target as quickly as possible to avoid problems with hole stability; (4) evaluation activities were reduced in scope; (5) geosteering observations for fracture access would be deduced from penetration rate, cuttings description and hydrocarbon in-flow; and (6) rather than use nitrogen, a novel air-injection MPD system was to be implemented. Drilling operations, delayed from the original schedule by capital constraints and lack of rig availability, were conducted from September 12 to November 11, 2004. The vertical and upper curved sections were drilled and lined through the problematic shale member without major stability problems. The top of the targeted Monterey was thought to be seen at the expected TVD of 10,000 ft where the 7-in. liner was set at a 60{sup o} hole angle. Significant oil and gas shows suggested the fractured interval anticipated at the heel location had been penetrated. A total of 2572 ft of 6 1/8-in. near-horizontal interval was placed in the shale section, extending planned well length by approximately 470 ft. Very little hydrocarbon in-flow was observed from fractures along the productive interval. This may be a result of the well trajectory falling underneath the Monterey fractured zone. Hydrocarbon observations, cuttings analysis and gamma-ray response indicated additional fractured intervals were accessed along the last {+-}900 ft of well length. The well was completed with a 2 7/8-in. tubing string set in a production packer in preparation for flow and swab tests to be conducted later by a service rig. The planned well time was estimated as 39 days and overall cost as $2.4 million. The actual results are 66 days at a total cost of $3.4 million. Well productivity responses during subsequent flow and swabbing tests were negative. The well failed to inflow and only minor amounts (a few barrels) of light oil were recovered. The lack of production may suggest that actual sustainable reservoir pressure is far less than anticipated. Temblor is currently planning to re-enter and clean out the well and run an Array Induction log (primarily for resistivity and correlation purposes), and an FMI log (for fracture detection). Depending on the results of these logs, an acidizing or re-drill program will be planned.

George Witter; Robert Knoll; William Rehm; Thomas Williams

2005-09-29T23:59:59.000Z

106

Welding Hot Cracking of Side Shell of Drilling-Well Oil Storage Ship  

Science Journals Connector (OSTI)

...Cracks were found in the weld metal (WM) of weld-section of side shell of drilling-well oil storage ship when performing post weld radiographic...

Zhi-wei Yu; Xiao-lei Xu

2014-11-01T23:59:59.000Z

107

Simulation of air and mist drilling for geothermal wells  

SciTech Connect

An air drilling model has been developed that accounts for cuttings and mist. Comparison of the model results with previous work shows this model to be more conservative. The equations developed are simple enough to be used in hand calculations, but the full capability of the model is more easily obtained with a computer program. Studies with the model show that volume requirements and standpipe pressures are significantly different for mist drilling compared with air drilling. An improved method for calculating downhole temperatures, pressures, fluid densities, and velocities during air drilling has been developed. Improvements on previous methods include the following. A fully transient thermal analysis of the wellbore and formation is used to determine the flowing temperatures. The effects of flow acceleration are included explicitly in the calculation. The slip velocity between the gas and the cuttings is determined by the use of a separate momentum equation for the cuttings. The possibility of critical flow in the wellbore is tested and appropriate changes in the volume flow rate and standpipe pressure are made automatically. The standpipe and flowing pressures are predicted. The analysis is conservative. The effect of the cuttings on the wellbore flow will tend to overpredict the required volume flow rates. In this paper, the basic equations of fluid flow for a gas with cuttings and mist are presented along with a numerical method for their solution. Several applications of this calculational method are given, showing the effect of flow rate and standpipe pressure in typical air and mist drilling situations.

Mitchell, R.F.

1983-11-01T23:59:59.000Z

108

U.S. Geothermal Drills Another Prolific Well at Neal Hot Springs Completes  

Open Energy Info (EERE)

Geothermal Drills Another Prolific Well at Neal Hot Springs Completes Geothermal Drills Another Prolific Well at Neal Hot Springs Completes Production Wells Needed for Project Jump to: navigation, search OpenEI Reference LibraryAdd to library Report: U.S. Geothermal Drills Another Prolific Well at Neal Hot Springs Completes Production Wells Needed for Project Abstract N/A Author U.S. Geothermal Inc. Published Publisher Not Provided, 2010 Report Number N/A DOI Not Provided Check for DOI availability: http://crossref.org Online Internet link for U.S. Geothermal Drills Another Prolific Well at Neal Hot Springs Completes Production Wells Needed for Project Citation U.S. Geothermal Inc.. 2010. U.S. Geothermal Drills Another Prolific Well at Neal Hot Springs Completes Production Wells Needed for Project. Boise Idaho: (!) . Report No.: N/A.

109

Validation of Innovative Exploration Technologies for Newberry Volcano: Map showing location of wells permitted, drilled and seismic test 2012  

DOE Data Explorer (OSTI)

Innovative Exploration Technologies for Newberry Volcano: Map showing location of wells permitted, drilled & seismic test, 2012

Jaffe, Todd

110

GRR/Section 5-NV-a - Drilling Well Development | Open Energy Information  

Open Energy Info (EERE)

5-NV-a - Drilling Well Development 5-NV-a - Drilling Well Development < GRR Jump to: navigation, search GRR-logo.png GEOTHERMAL REGULATORY ROADMAP Roadmap Home Roadmap Help List of Sections Section 5-NV-a - Drilling Well Development 05NVADrillingWellDevelopment.pdf Click to View Fullscreen Contact Agencies Nevada Division of Minerals Nevada Division of Water Resources Regulations & Policies Nevada Revised Statutes (NRS) Nevada Administrative Code (NAC) Triggers None specified Click "Edit With Form" above to add content 05NVADrillingWellDevelopment.pdf 05NVADrillingWellDevelopment.pdf Error creating thumbnail: Page number not in range. Error creating thumbnail: Page number not in range. Flowchart Narrative A person may not drill or operate a geothermal well or drill an exploratory well without obtaining a permit from the Administrator of the Nevada

111

Productivity and injectivity of horizontal wells. Quarterly report, July 1, 1994--September 30, 1994  

SciTech Connect

This quarterly report is entirely devoted to presenting samples of the results of the data analyses for horizontal drilling studies. In addition, a data compilation of Excel worksheets containing data on two-phase flow measurements at the Marathon Oil Company is discussed. Complete data analyses will be presented in the next annual report.

Fayers, F.J.

1995-01-01T23:59:59.000Z

112

USE OF CUTTING-EDGE HORIZONTAL AND UNDERBALANCED DRILLING TECHNOLOGIES AND SUBSURFACE SEISMIC TECHNIQUES TO EXPLORE, DRILL AND PRODUCE RESERVOIRED OIL AND GAS FROM THE FRACTURED MONTEREY BELOW 10,000 FT IN THE SANTA MARIA BASIN OF CALIFORNIA  

SciTech Connect

This project was undertaken to demonstrate that oil and gas can be drilled and produced safely and economically from a fractured Monterey reservoir in the Santa Maria Basin of California by employing horizontal wellbores and underbalanced drilling technologies. Two vertical wells were previously drilled in this area by Temblor Petroleum with heavy mud and conventional completions; neither was commercially productive. A new well was drilled by the project team in 2004 with the objective of accessing an extended length of oil-bearing, high-resistivity Monterey shale via a horizontal wellbore, while implementing managed-pressure drilling (MPD) techniques to avoid formation damage. Initial project meetings were conducted in October 2003. The team confirmed that the demonstration well would be completed open-hole to minimize productivity impairment. Following an overview of the geologic setting and local field experience, critical aspects of the application were identified. At the pre-spud meeting in January 2004, the final well design was confirmed and the well programming/service company requirements assigned. Various design elements were reduced in scope due to significant budgetary constraints. Major alterations to the original plan included: (1) a VSP seismic survey was delayed to a later phase; (2) a new (larger) surface hole would be drilled rather than re-enter an existing well; (3) a 7-in. liner would be placed into the top of the Monterey target as quickly as possible to avoid problems with hole stability; (4) evaluation activities were reduced in scope; (5) geosteering observations for fracture access would be deduced from penetration rate, cuttings description and hydrocarbon in-flow; and (6) rather than use nitrogen, a novel air-injection MPD system was to be implemented. Drilling operations, delayed from the original schedule by capital constraints and lack of rig availability, were conducted from September 12 to November 11, 2004. The vertical and upper curved sections were drilled and lined through the problematic shale member without major stability problems. The top of the targeted Monterey was thought to be seen at the expected TVD of 10,000 ft where the 7-in. liner was set at a 60{sup o} hole angle. Significant oil and gas shows suggested the fractured interval anticipated at the heel location had been penetrated. A total of 2572 ft of 6.-in. near-horizontal interval was placed in the shale section, extending planned well length by approximately 470 ft. Very little hydrocarbon in-flow was observed from fractures along the productive interval. This may be a result of the well trajectory falling underneath the Monterey fractured zone. Hydrocarbon observations, cuttings analysis and gamma-ray response indicated additional fractured intervals were accessed along the last {+-}900 ft of well length. The well was completed with a 2 7/8-in. tubing string set in a production packer in preparation for flow and swab tests to be conducted later by a service rig. The planned well time was estimated as 39 days and overall cost as $2.4 million. The actual results are 66 days at a total cost of $3.4 million. Well productivity responses during subsequent flow and swabbing tests were negative. The well failed to inflow and only minor amounts (a few barrels) of light oil were recovered. The lack of production may suggest that actual sustainable reservoir pressure is far less than anticipated. Temblor is currently investigating the costs and operational viability of re-entering the well and conducting an FMI (fracture detection) log and/or an acid stimulation. No final decision or detailed plans have been made regarding these potential interventions at this time.

George Witter; Robert Knoll; William Rehm; Thomas Williams

2005-02-01T23:59:59.000Z

113

Prediction of lateral variability in fracture intensity using multicomponent shear-wave surface seismic as a precursor to horizontal drilling in the Austin Chalk  

Science Journals Connector (OSTI)

......represents the horizontal borehole. The open square boxes on the horizontal borehole are mudlogger determined...lines intersecting the borehole represent fractures...measurable, even if y is large. However, the differencein...support of a horizontal drilling program. This method......

Michael C. Mueller

1991-12-01T23:59:59.000Z

114

U.S. Nominal Cost per Foot of Dry Wells Drilled (Dollars per...  

Annual Energy Outlook 2012 (EIA)

Dry Wells Drilled (Dollars per Foot) U.S. Nominal Cost per Foot of Dry Wells Drilled (Dollars per Foot) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9...

115

GRR/Section 5-TX-a - Drilling and Well Development | Open Energy  

Open Energy Info (EERE)

GRR/Section 5-TX-a - Drilling and Well Development GRR/Section 5-TX-a - Drilling and Well Development < GRR Jump to: navigation, search GRR-logo.png GEOTHERMAL REGULATORY ROADMAP Roadmap Home Roadmap Help List of Sections Section 5-TX-a - Drilling and Well Development 05TXADrillingAndWellDevelopment.pdf Click to View Fullscreen Contact Agencies Railroad Commission of Texas Texas Water Development Board Regulations & Policies 16 TAC 3.5: Application To Drill, Deepen, Reenter, or Plug Back 16 TAC 3.78: Fees and Financial Security Requirements 16 TAC 3.37: Statewide Spacing Rule 16 TAC 3.38: Well Densities 16 TAC 3.39: Proration and Drilling Units: Contiguity of Acreage and Exception 16 TAC 3.33: Geothermal Resource Production Test Forms Required Triggers None specified Click "Edit With Form" above to add content

116

GRR/Section 5-CA-a - Drilling and Well Development | Open Energy  

Open Energy Info (EERE)

5-CA-a - Drilling and Well Development 5-CA-a - Drilling and Well Development < GRR Jump to: navigation, search GRR-logo.png GEOTHERMAL REGULATORY ROADMAP Roadmap Home Roadmap Help List of Sections Section 5-CA-a - Drilling and Well Development 05CAADrillingApplicationProcess (1).pdf Click to View Fullscreen Contact Agencies California Department of Conservation, Division of Oil, Gas, and Geothermal Resources Triggers None specified Click "Edit With Form" above to add content 05CAADrillingApplicationProcess (1).pdf 05CAADrillingApplicationProcess (1).pdf Error creating thumbnail: Page number not in range. Error creating thumbnail: Page number not in range. Flowchart Narrative The California Department of Conservation, Division of Oil and Gas (DOGGR) administers geothermal well drilling activities (permitting, drilling,

117

Steerable BHAs drill storage wells with difficult trajectories. [Bottom Hole Assembly  

SciTech Connect

The use of steerable downhole motor assemblies allows greater variation in well bore trajectory for drilling gas and oil storage wells in salt domes in areas with surface site restrictions. With modern directional drilling tools, the cavern wells are drilled vertically, kicked off in an S turn, and then finished with a vertical section. The last 100 m of a cavern well above the last cemented casing shoe must be vertical because of the technical demands of brining and completion. To date, Kavernen Bauund Betriebs-GmbH has successfully drilled and completed three directional cavern boreholes in Germany. These directional drilling techniques have also been used successfully for vertical boreholes with strict deviation limits. The paper describes this technology.

Gomm, H.; Peters, L. (Kavernen Bau- und Betriebs-GmbH, Hannover (Germany))

1993-07-19T23:59:59.000Z

118

Technical and economic evaluation of selected compact drill rigs for drilling 10,000 foot geothermal production wells  

SciTech Connect

This report summarizes the investigation and evaluation of several {open_quotes}compact{close_quotes} drill rigs which could be used for drilling geothermal production wells. Use of these smaller rigs would save money by reducing mobilization costs, fuel consumption, crew sizes, and environmental impact. Advantages and disadvantages of currently-manufactured rigs are identified, and desirable characteristics for the {open_quotes}ideal{close_quotes} compact rig are defined. The report includes a detailed cost estimate of a specific rig, and an evaluation of the cost/benefit ratio of using this rig. Industry contacts for further information are given.

Huttrer, G.W. [Geothermal Management Company, Inc., Frisco, CO (United States)

1997-11-01T23:59:59.000Z

119

Experimental and simulation studies of zone isolation in horizontal wells  

E-Print Network (OSTI)

wellbore plug in the horizontal section downstream of the problem zone, (iii) spotting and squeezing a formation gel in between the straddle wellbore plug system into the problem zone, and (iv) washing out the excess formation gel and the wellbore plug...

Tan, Joo Sitt

1997-01-01T23:59:59.000Z

120

U.S. Footage Drilled for Natural Gas Exploratory Wells (Thousand...  

Annual Energy Outlook 2012 (EIA)

Wells (Thousand Feet) U.S. Footage Drilled for Natural Gas Exploratory Wells (Thousand Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1940's...

Note: This page contains sample records for the topic "horizontal wells drilling" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


121

U.S. Footage Drilled for Natural Gas Developmental Wells (Thousand...  

Annual Energy Outlook 2012 (EIA)

Developmental Wells (Thousand Feet) U.S. Footage Drilled for Natural Gas Developmental Wells (Thousand Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8...

122

HETEROGENEOUS SHALLOW-SHELF CARBONATE BUILDUPS IN THE PARADOX BASIN, UTAH AND COLORADO: TARGETS FOR INCREASED OIL PRODUCTION AND RESERVES USING HORIZONTAL DRILLING TECHNIQUES  

SciTech Connect

The Paradox Basin of Utah, Colorado, Arizona, and New Mexico contains nearly 100 small oil fields producing from carbonate buildups within the Pennsylvanian (Desmoinesian) Paradox Formation. These fields typically have one to 10 wells with primary production ranging from 700,000 to 2,000,000 barrels (111,300-318,000 m{sup 3}) of oil per field and a 15 to 20 percent recovery rate. At least 200 million barrels (31.8 million m{sup 3}) of oil will not be recovered from these small fields because of inefficient recovery practices and undrained heterogeneous reservoirs. Several fields in southeastern Utah and southwestern Colorado are being evaluated as candidates for horizontal drilling and enhanced oil recovery from existing, vertical, field wells based upon geological characterization and reservoir modeling case studies. Geological characterization on a local scale is focused on reservoir heterogeneity, quality, and lateral continuity, as well as possible reservoir compartmentalization, within these fields. This study utilizes representative cores, geophysical logs, and thin sections to characterize and grade each field's potential for drilling horizontal laterals from existing development wells. The results of these studies can be applied to similar fields elsewhere in the Paradox Basin and the Rocky Mountain region, the Michigan and Illinois Basins, and the Midcontinent region. This report covers research activities for the first half of the third project year (April 6 through October 5, 2002). This work included capillary pressure/mercury injection analysis, scanning electron microscopy, and pore casting on selected samples from Cherokee and Bug fields, Utah. The diagenetic fabrics and porosity types found at these fields are indicators of reservoir flow capacity, storage capacity, and potential for enhanced oil recovery via horizontal drilling. The reservoir quality of Cherokee and Bug fields has been affected by multiple generations of dissolution, anhydrite plugging, and various types of cementation which act as barriers or baffles to fluid flow. The most significant diagenetic characteristics are microporosity (Cherokee field) and micro-boxwork porosity (Bug field), as shown from porethroat radii histograms, and saturation profiles generated from the capillary pressure/mercury injection analysis, and identified by scanning electron microscopy and pore casting. These porosity types represent important sites for untapped hydrocarbons and primary targets for horizontal drilling. Technology transfer activities consisted of exhibiting a booth display of project materials at the Rocky Mountain Section meeting of the American Association of Petroleum Geologists, a technical presentation, and publications. The project home page was updated for the Utah Geological Survey Internet web site.

Thomas C. Chidsey, Jr.

2002-12-01T23:59:59.000Z

123

Productivity and injectivity of horizontal wells. Annual report, March 10, 1995--March 9, 1996  

SciTech Connect

The DOE approval for the annual renewal of the research grant to the Stanford Project on the Productivity and Injectivity of Horizontal Wells was received in early March 1995. Project goals include the advanced modeling of horizontal wells; investigation and incorporation of the effects of reservoir heterogeneities; development of improved methods of calculating multi-phase pressure drops within wellbores; development of multi-well models; testing of horizontal well models with field examples; EOR applications; and application studies and their optimization.

Aziz, K.; Hewett, T.

1996-05-01T23:59:59.000Z

124

GRR/Section 5-AK-a - Drilling and Well Development | Open Energy  

Open Energy Info (EERE)

GRR/Section 5-AK-a - Drilling and Well Development GRR/Section 5-AK-a - Drilling and Well Development < GRR Jump to: navigation, search GRR-logo.png GEOTHERMAL REGULATORY ROADMAP Roadmap Home Roadmap Help List of Sections Section 5-AK-a - Drilling and Well Development 05AKADrillingWellDevelopment.pdf Click to View Fullscreen Contact Agencies Alaska Oil and Gas Conservation Commission Alaska Department of Natural Resources Regulations & Policies Alaska Statutes Alaska Administrative Code Triggers None specified Click "Edit With Form" above to add content 05AKADrillingWellDevelopment.pdf Error creating thumbnail: Page number not in range. Error creating thumbnail: Page number not in range. Error creating thumbnail: Page number not in range. Flowchart Narrative All wells drilled in search or in support of the recovery of geothermal

125

GRR/Section 5-WA-a - Drilling and Well Development | Open Energy  

Open Energy Info (EERE)

GRR/Section 5-WA-a - Drilling and Well Development GRR/Section 5-WA-a - Drilling and Well Development < GRR Jump to: navigation, search GRR-logo.png GEOTHERMAL REGULATORY ROADMAP Roadmap Home Roadmap Help List of Sections Section 5-WA-a - Drilling and Well Development 5-WA-a.pdf Click to View Fullscreen Contact Agencies Washington State Department of Natural Resources Regulations & Policies Geothermal Act 78.60 RCW Geothermal Rules 332-17 WAC Triggers None specified In Washington geothermal drilling and well development are regulated by the Washington State Department of Natural Resources (WSDNR). Geothermal production wells and core holes deeper than 750ft require the developer go through the whole WSDNR permitting process (which requires a public hearing) and require that the developer complete the State Environmental

126

Phase 2 Reese River Geothermal Project Slim Well 56-4 Drilling And Testing  

Open Energy Info (EERE)

Phase 2 Reese River Geothermal Project Slim Well 56-4 Drilling And Testing Phase 2 Reese River Geothermal Project Slim Well 56-4 Drilling And Testing Jump to: navigation, search GEOTHERMAL ENERGYGeothermal Home Report: Phase 2 Reese River Geothermal Project Slim Well 56-4 Drilling And Testing Details Activities (6) Areas (1) Regions (0) Abstract: This report covers the drilling and testing of the slim well 56-4 at the Reese River Geothermal Project in Lander County, Nevada. This well was partially funded through a GRED III Cooperative Funding Agreement # DE-FC36-04GO14344, from USDOE. Author(s): William R. Henkle, Joel Ronne Published: Geothermal Technologies Legacy Collection, 2008 Document Number: Unavailable DOI: Unavailable Source: View Original Report Compound and Elemental Analysis At Reese River Area (Henkle & Ronne, 2008)

127

Geothermal Well Costs and their Sensitivities to Changes in Drilling and Completion Operations  

SciTech Connect

This paper presents a detailed analysis of the costs of drilling and completing geothermal wells. The basis for much of the analysis is a computer-simulation-based model which calculates and accrues operational costs involved in drilling and completing a well. Geothermal well costs are discussed in general, with special emphasis on variations among different geothermal areas in the United States, effects of escalation and inflation over the past few years, and comparisons of geothermal drilling costs with those for oil and gas wells. Cost differences between wells for direct use of geothermal energy and those for electric generation, are also indicated. In addition, a breakdown of total well cost into its components is presented. This provides an understanding of the relative contributions of different operations in drilling and completions. A major portion of the cost in many geothermal wells is from encountered troubles, such as lost circulation, cementing difficulties, and fishing. These trouble costs are considered through both specific examples and statistical treatment of drilling and completions problems. The sensitivities of well costs to variations in several drilling and completion parameters are presented. The mode1 makes it possible to easily vary parameters such as rates of penetration; bit lifetimes; bit rental, or rig costs; delay times; number of cement plugs; etc. are compared.

Carson, C. C.; Lin, Y.T.

1981-01-01T23:59:59.000Z

128

Decisions with Multiple Environmental Objectives. The Siting of Oil Drilling Wells in Norway  

Science Journals Connector (OSTI)

This multiattribute analysis shows how “the seven steps of decision analysis” is applied to the siting of oil drilling wells in Northern Norway. The study includes ... an assessment of the frequency of accidents ...

Knut L. Seip

1991-01-01T23:59:59.000Z

129

Carbon Sequestration Partner Initiates Drilling of CO2 Injection Well in  

Energy.gov (U.S. Department of Energy (DOE)) Indexed Site

Sequestration Partner Initiates Drilling of CO2 Injection Sequestration Partner Initiates Drilling of CO2 Injection Well in Illinois Basin Carbon Sequestration Partner Initiates Drilling of CO2 Injection Well in Illinois Basin February 17, 2009 - 12:00pm Addthis Washington, D.C. -- The Midwest Geological Sequestration Consortium (MGSC), one of seven regional partnerships created by the U.S. Department of Energy (DOE) to advance carbon sequestration technologies nationwide, has begun drilling the injection well for their large-scale carbon dioxide (CO2) injection test in Decatur, Illinois. The test is part of the development phase of the Regional Carbon Sequestration Partnerships program, an Office of Fossil Energy initiative launched in 2003 to determine the best approaches for capturing and permanently storing gases that can contribute

130

Phase 2 drilling operations at the Long Valley Exploratory Well (LVF 51--20)  

SciTech Connect

This report describes the second drilling phase, completed to a depth of 7588 feet in November 1991, of the Long Valley Exploratory Well near Mammoth Lakes, California. The well in Long Valley Caldera is planned to reach an ultimate depth of 20,000 feet or a bottomhole temperature of 500{degrees}C (whichever comes first). There will be four drilling phases, at least a year apart with scientific experiments in the wellbore between active drilling periods. Phase 1 drilling in 1989 was completed with 20 in. casing from surface to a depth of 2558 ft., and a 3.8 in. core hole was drilled below the shoe to a depth of 2754 in. Phase 2 included a 17-{1/2} in. hole out of the 20 in. shoe, with 13-3/8 in. casing to 6825 ft., and continuous wireline coring below that to 7588 ft. This document comprises a narrative log of the daily activities, the daily drilling reports, mud logger's reports, summary of drilling fluids used, and other miscellaneous records.

Finger, J.T.; Jacobson, R.D.

1992-06-01T23:59:59.000Z

131

Hydraulics of horizontal wells in fractured shallow aquifer systems Eungyu Parka,*, Hongbin Zhanb  

E-Print Network (OSTI)

Hydraulics of horizontal wells in fractured shallow aquifer systems Eungyu Parka,*, Hongbin Zhanb Accepted 1 May 2003 Abstract An analysis of groundwater hydraulic head in the vicinity of a horizontal well in fractured or porous aquifers considering confined, leaky confined, and water-table aquifer boundary

Zhan, Hongbin

132

GRR/Section 5-UT-a - Drilling and Well Development | Open Energy  

Open Energy Info (EERE)

GRR/Section 5-UT-a - Drilling and Well Development GRR/Section 5-UT-a - Drilling and Well Development < GRR Jump to: navigation, search GRR-logo.png GEOTHERMAL REGULATORY ROADMAP Roadmap Home Roadmap Help List of Sections Section 5-UT-a - Drilling and Well Development 05UTADrillingAndWellDevelopment.pdf Click to View Fullscreen Contact Agencies Utah Division of Water Rights Regulations & Policies Utah Geothermal Resource Conservation Act Utah Administrative Code Section R655-1 Triggers None specified Click "Edit With Form" above to add content 05UTADrillingAndWellDevelopment.pdf 05UTADrillingAndWellDevelopment.pdf Error creating thumbnail: Page number not in range. Error creating thumbnail: Page number not in range. Flowchart Narrative Although not regulated under the Administrative Rules for Water Wells,

133

Horizontal Well Placement Optimization in Gas Reservoirs Using Genetic Algorithms  

E-Print Network (OSTI)

......................................................................................................................... 65 x LIST OF FIGURES FIGURE Page 1 Algorithm for single generation of GA.... well location......................................................... 40 11 Maximum function fitness value vs generation number for Case 1........... 41 12 Case 2 fitness value vs. well location...

Gibbs, Trevor Howard

2011-08-08T23:59:59.000Z

134

GRR/Section 5-MT-a - Drilling and Well Development | Open Energy  

Open Energy Info (EERE)

GRR/Section 5-MT-a - Drilling and Well Development GRR/Section 5-MT-a - Drilling and Well Development < GRR Jump to: navigation, search GRR-logo.png GEOTHERMAL REGULATORY ROADMAP Roadmap Home Roadmap Help List of Sections Section 5-MT-a - Drilling and Well Development 05MTADrillingAndWellDevelopment (1).pdf Click to View Fullscreen Contact Agencies Montana Department of Natural Resources & Conservation Montana Department of Environmental Quality Regulations & Policies MCA 37-43-104: Monitoring Wells MCA 37-43-302: License Requirements MCA 37-43-306: Bonding Requirements Triggers None specified Click "Edit With Form" above to add content 05MTADrillingAndWellDevelopment (1).pdf Error creating thumbnail: Page number not in range. Error creating thumbnail: Page number not in range. Error creating thumbnail: Page number not in range.

135

GRR/Section 5-CO-a - Drilling and Well Development | Open Energy  

Open Energy Info (EERE)

CO-a - Drilling and Well Development CO-a - Drilling and Well Development < GRR Jump to: navigation, search GRR-logo.png GEOTHERMAL REGULATORY ROADMAP Roadmap Home Roadmap Help List of Sections Section 5-CO-a - Drilling and Well Development 05COADrillingAndWellDevelopment (1).pdf Click to View Fullscreen Contact Agencies Colorado Division of Water Resources Colorado Oil and Gas Conservation Commission Regulations & Policies Rules and Regulations for Permitting the Development and Appropriation of Geothermal Resources Through the Use of Wells CRS 37-90.5-107 Triggers None specified Click "Edit With Form" above to add content 05COADrillingAndWellDevelopment (1).pdf Error creating thumbnail: Page number not in range. Error creating thumbnail: Page number not in range. Error creating thumbnail: Page number not in range.

136

Heterogeneous Shallow-Shelf Carbonate Buildups in the Paradox Basin, Utah and Colorado: Targets for Increased Oil Production and Reserves Using Horizontal Drilling Techniques  

SciTech Connect

The Paradox Basin of Utah, Colorado, Arizona, and New Mexico contains nearly 100 small oil fields producing from carbonate buildups within the Pennsylvanian (Desmoinesian) Paradox Formation. These fields typically have one to 10 wells with primary production ranging from 700,000 to 2,000,000 barrels (111,300-318,000 m{sup 3}) of oil per field and a 15 to 20 percent recovery rate. At least 200 million barrels (31.8 million m{sup 3}) of oil will not be recovered from these small fields because of inefficient recovery practices and undrained heterogeneous reservoirs. Several fields in southeastern Utah and southwestern Colorado are being evaluated as candidates for horizontal drilling and enhanced oil recovery from existing vertical wells based upon geological characterization and reservoir modeling case studies. Geological characterization on a local scale is focused on reservoir heterogeneity, quality, and lateral continuity, as well as possible reservoir compartmentalization, within these fields. This study utilizes representative cores, geophysical logs, and thin sections to characterize and grade each field's potential for drilling horizontal laterals from existing development wells. The results of these studies can be applied to similar fields elsewhere in the Paradox Basin and the Rocky Mountain region, the Michigan and Illinois Basins, and the Midcontinent region. This report covers research activities for the first half of the fourth project year (April 6 through October 5, 2003). The work included (1) analysis of well-test data and oil production from Cherokee and Bug fields, San Juan County, Utah, and (2) diagenetic evaluation of stable isotopes from the upper Ismay and lower Desert Creek zones of the Paradox Formation in the Blanding sub-basin, Utah. Production ''sweet spots'' and potential horizontal drilling candidates were identified for Cherokee and Bug fields. In Cherokee field, the most productive wells are located in the thickest part of the mound facies of the upper Ismay zone, where microporosity is well developed. In Bug field, the most productive wells are located structurally downdip from the updip porosity pinch out in the dolomitized lower Desert Creek zone, where micro-box-work porosity is well developed. Microporosity and micro-box-work porosity have the greatest hydrocarbon storage and flow capacity, and potential horizontal drilling target in these fields. Diagenesis is the main control on the quality of Ismay and Desert Creek reservoirs. Most of the carbonates present within the lower Desert Creek and Ismay have retained a marine-influenced carbon isotope geochemistry throughout marine cementation as well as through post-burial recycling of marine carbonate components during dolomitization, stylolitization, dissolution, and late cementation. Meteoric waters do not appear to have had any effect on the composition of the dolomites in these zones. Light oxygen values obtained from reservoir samples for wells located along the margins or flanks of Bug field may be indicative of exposure to higher temperatures, to fluids depleted in {sup 18}O relative to sea water, or to hypersaline waters during burial diagenesis. The samples from Bug field with the lightest oxygen isotope compositions are from wells that have produced significantly greater amounts of hydrocarbons. There is no significant difference between the oxygen isotope compositions from lower Desert Creek dolomite samples in Bug field and the upper Ismay limestones and dolomites from Cherokee field. Carbon isotopic compositions for samples from Patterson Canyon field can be divided into two populations: isotopically heavier mound cement and isotopically lighter oolite and banded cement. Technology transfer activities consisted of exhibiting a booth display of project materials at the annual national convention of the American Association of Petroleum Geologists, a technical presentation, a core workshop, and publications. The project home page was updated on the Utah Geological Survey Internet web site.

Thomas C. Chidsey; Kevin McClure; Craig D. Morgan

2003-10-05T23:59:59.000Z

137

GRR/Section 5-ID-a - Drilling and Well Development | Open Energy  

Open Energy Info (EERE)

ID-a - Drilling and Well Development ID-a - Drilling and Well Development < GRR Jump to: navigation, search GRR-logo.png GEOTHERMAL REGULATORY ROADMAP Roadmap Home Roadmap Help List of Sections Section 5-ID-a - Drilling and Well Development 05IDADrillingWellDevelopment.pdf Click to View Fullscreen Contact Agencies Idaho Department of Water Resources Regulations & Policies IC §42-233: Appropriation of Water, Geothermal IC §42-4003: Permits IC §42-4004: Processing Applications IC §42-4011: Name of Owner Triggers None specified Click "Edit With Form" above to add content Best Practices Community outreach Talk to the local county Potential Roadblocks Incomplete applications result in longer approval times by IDWR 05IDADrillingWellDevelopment.pdf Error creating thumbnail: Page number not in range.

138

GRR/Section 5-HI-a - Drilling and Well Development | Open Energy  

Open Energy Info (EERE)

GRR/Section 5-HI-a - Drilling and Well Development GRR/Section 5-HI-a - Drilling and Well Development < GRR Jump to: navigation, search GRR-logo.png GEOTHERMAL REGULATORY ROADMAP Roadmap Home Roadmap Help List of Sections Section 5-HI-a - Drilling and Well Development 05HIADrillingAndModificationOfWellsForInjectionUsePermit (1).pdf Click to View Fullscreen Contact Agencies Hawaii Department of Land and Natural Resources Engineering Division Regulations & Policies Hawaii Administrative Code §13-183-65 Draft Rules Triggers None specified Click "Edit With Form" above to add content 05HIADrillingAndModificationOfWellsForInjectionUsePermit (1).pdf Error creating thumbnail: Page number not in range. Error creating thumbnail: Page number not in range. Error creating thumbnail: Page number not in range.

139

GRR/Section 5-OR-a - Drilling and Well Development | Open Energy  

Open Energy Info (EERE)

5-OR-a - Drilling and Well Development 5-OR-a - Drilling and Well Development < GRR Jump to: navigation, search GRR-logo.png GEOTHERMAL REGULATORY ROADMAP Roadmap Home Roadmap Help List of Sections Section 5-OR-a - Drilling and Well Development 05ORADrillingAndWellDevelopment.pdf Click to View Fullscreen Contact Agencies Oregon Department of Geology and Mineral Industries Oregon Water Resources Department Oregon Department of Fish and Wildlife Oregon Department of Environmental Quality Oregon Department of Land Conservation and Development Oregon Department of State Lands Oregon Department of Energy Oregon Parks and Recreation Department Regulations & Policies ORS 522.005(11) ORS 522.025 ORS 522.115 ORS 522.125 ORS 522.135 Triggers None specified Click "Edit With Form" above to add content 05ORADrillingAndWellDevelopment.pdf

140

rillEdge is a software system that provides real-time deci-sion support when drilling oil wells. Decisions are sup-  

E-Print Network (OSTI)

D rillEdge is a software system that provides real-time deci- sion support when drilling oil wells developed DrillEdge to reduce the cost and decrease the probability of fail- ures in oil well drilling. Currently, DrillEdge continuously mon- itors around 30 oil well drilling operations in parallel for sever

Aamodt, Agnar

Note: This page contains sample records for the topic "horizontal wells drilling" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


141

Application of horizontal wells in steeply dipping reservoirs  

E-Print Network (OSTI)

of the Provincia field . . . 2. 3 Regional structural style cross-section of the Provincia field . . . . . 2. 4 Typical Gamma-Ray log - well Santos 111 10 3. 1 Reservoir simulation area 13 3. 2 General structural cross-section 15 3. 3 Stratigraphic cross... into the Suerte, Santos and Conde areas. 2. 2 Stratigraphic column The stratigraphic sequence in the field involves rocks from Tertiary to recent age (Fig. 2. 2). The source rocks are believed to be Cretaceous. The presence of hydrocarbons has been identified...

Lopez Navarro, Jose David

2012-06-07T23:59:59.000Z

142

Phase III Drilling Operations at the Long Valley Exploratory Well (LVF 51-20)  

SciTech Connect

During July-September, 1998, a jointly funded drilling operation deepened the Long Valley Exploratory Well from 7178 feet to 9832 feet. This was the third major drilling phase of a project that began in 1989, but had sporadic progress because of discontinuities in tiding. Support for Phase III came from the California Energy Commission (CEC), the International Continental Drilling Program (ICDP), the US Geological Survey (USGS), and DOE. Each of these agencies had a somewhat different agenda: the CEC wants to evaluate the energy potential (specifically energy extraction from magma) of Long Valley Caldera; the ICDP is studying the evolution and other characteristics of young, silicic calderas; the USGS will use this hole as an observatory in their Volcano Hazards program; and the DOE, through Sandia, has an opportunity to test new geothermal tools and techniques in a realistic field environment. This report gives a description of the equipment used in drilling and testing; a narrative of the drilling operations; compiled daily drilling reports; cost information on the project; and a brief summary of engineering results related to equipment performance and energy potential. Detailed description of the scientific results will appear in publications by the USGS and other researchers.

Finger, J.T.; Jacobson, R.D.

1999-06-01T23:59:59.000Z

143

Pressure Transient Analysis for Multi-stage Fractured Horizontal Wells in Shale Gas Reservoirs  

Science Journals Connector (OSTI)

This article presents the PTA on the multi-stage fractured horizontal well in shale gas reservoirs incorporating desorption and diffusive flow in ... considering the mechanisms of desorption and diffusion in shale

Jingjing Guo; Liehui Zhang; Haitao Wang; Guoqing Feng

2012-07-01T23:59:59.000Z

144

Development of an inflow performance relationship (IPR) for a slanted/horizontal well  

SciTech Connect

Since 1968, the Vogel equation has been used extensively and successfully for analyzing the inflow performance relationship (IPR) of flowing oil wells under solution-gas drive. Oil well productivity can be rapidly estimated using the Vogel IPR curve and well outflow performance. However, the Vogel curve was originally developed for conventional vertical wells and may not be valid for slanted and horizontal wells. This report presents the development of IPR's for slanted and horizontal wells by using a vertical/horizontal/slanted well reservoir simulator. The generated IPR's are found to be similar to the parabolic characteristic of the Vogel curve. Several application examples are included to illustrate the use of the newly generated curves. 12 refs., 15 figs., 25 tabs.

Cheng, A.M.

1990-03-01T23:59:59.000Z

145

USE OF SLIMHOLE DRILLING TO REDUCE WELL COSTS 30-50%: ARNIM PROSPECT  

SciTech Connect

This report highlights the drilling of two shallow oil wells in Fayette County, Texas. The operator of these two wells was Stanton Mineral Development, Inc. The aim of this project was to successfully complete the two (2) wells, emphasizing tight oversight of the technological aspects, neglect of which are the primary causes of failure in this mature producing region as well as unnecessarily expensive wells. Discussions contained here within are not limited to just the execution of the project itself, but a historical and technical analysis which forms a basis for the decisions made both during drilling and completion. Additionally, there is substantial dialogue covering the financial benefits associated with the findings of this project.

WM. Stanton McDonald; Christopher M. Long

2002-06-13T23:59:59.000Z

146

Formation damage in underbalanced drilling operations  

E-Print Network (OSTI)

Formation damage has long been recognized as a potential source of reduced productivity and injectivity in both horizontal and vertical wells. From the moment that the pay zone is being drilled until the well is put on production, a formation...

Reyes Serpa, Carlos Alberto

2012-06-07T23:59:59.000Z

147

Temperature histories in geothermal wells: survey of rock thermomechanical properties and drilling, production, and injection case studies  

SciTech Connect

Thermal and mechanical properties for geothermal formations are tabulated for a range of temperatures and stress conditions. Data was obtained from the technical literature and direct contacts with industry. Thermal properties include heat capacity, conductivity, and diffusivity. Undisturbed geothermal profiles are also presented. Mechanical properties include Youngs modulus and Poisson ratio. GEOTEMP thermal simulations of drilling, production and injection are reported for two geothermal regions, the hot dry rock area near Los Alamos and the East Mesa field in the Imperial Valley. Actual drilling, production, and injection histories are simulated. Results are documented in the form of printed GEOTEMP output and plots of temperatures versus depth, radius, and time. Discussion and interpretation of the results are presented for drilling and well completion design to determine: wellbore temperatures during drilling as a function of depth; bit temperatures over the drilling history; cement temperatures from setting to the end of drilling; and casing and formation temperatures during drilling, production, and injection.

Goodman, M.A.

1981-07-01T23:59:59.000Z

148

Productivity and injectivity of horizontal wells. Annual report, March 10, 1996--March 9, 1997  

SciTech Connect

Progress is reported on the following tasks: advanced modeling of horizontal wells; heterogeneous effects of reservoirs; development of improved methods for calculating multi-phase pressure drops within the wellbore; pseudo-functions; development of multi-well models;testing of HW models with field examples; enhanced oil recovery applications; and application studies and their optimization.

Aziz, K.; Hewett, T.A.; Arbabi, S.; Smith, M.

1997-06-01T23:59:59.000Z

149

Productivity and injectivity of horizontal wells. Annual report, March 10, 1993--March 9, 1994  

SciTech Connect

In this report, the investigators review a range of reservoir scenarios in which horizontal wells can be advantageous and discuss some of the modeling problems associated with calculating well connection factors, productivity indices, coning behavior and well two-phase pressure drops. We show illustrative coning calculations and the implications of the well model on distribution of post-breakthrough gas saturations. Such calculations then open up the possibility of determining optimal recompletion strategies and/or additional hydraulic fracturing.

Fayers, F.J.; Aziz, K.; Hewett, T.A.; Arbabi, S.

1994-10-01T23:59:59.000Z

150

Potential impacts of artificial intelligence expert systems on geothermal well drilling costs:  

SciTech Connect

The Geothermal research Program of the US Department of Energy (DOE) has as one of its goals to reduce the cost of drilling geothermal wells by 25 percent. To attain this goal, DOE continuously evaluates new technologies to determine their potential in contributing to the Program. One such technology is artifical intelligence (AI), a branch of computer science that, in recent years, has begun to impact the marketplace in a number of fields. Expert systems techniques can (and in some cases, already have) been applied to develop computer-based ''advisors'' to assist drilling personnel in areas such as designing mud systems, casing plans, and cement programs, optimizing drill bit selection and bottom hole asssembly (BHA) design, and alleviating lost circulation, stuck pipe, fishing, and cement problems. Intelligent machines with sensor and/or robotic directly linked to AI systems, have potential applications in areas of bit control, rig hydraulics, pipe handling, and pipe inspection. Using a well costing spreadsheet, the potential savings that could be attributed to each of these systems was calculated for three base cases: a dry steam well at The Geysers, a medium-depth Imerial Valley well, and a deep Imperial Valley well. Based on the average potential savings to be realized, expert systems for handling lost circulations problems and for BHA design are the most likely to produce significant results. Automated bit control and rig hydraulics also exhibit high potential savings, but these savings are extremely sensitive to the assumptions of improved drilling efficiency and the cost of these sytems at the rig. 50 refs., 19 figs., 17 tabs.

Satrape, J.V.

1987-11-24T23:59:59.000Z

151

DESIGN AND IMPLEMENTATION OF A CO2 FLOOD UTILIZING ADVANCED RESERVOIR CHARACTERIZATION AND HORIZONTAL INJECTION WELLS IN A SHALLOW SHELF CARBONATE APPROACHING WATERFLOOD DEPLETION  

SciTech Connect

The purpose of this project was to economically design an optimum carbon dioxide (CO{sub 2}) flood for a mature waterflood nearing its economic abandonment. The original project utilized advanced reservoir characterization and CO{sub 2} horizontal injection wells as the primary methods to redevelop the South Cowden Unit (SCU). The development plans; project implementation and reservoir management techniques were to be transferred to the public domain to assist in preventing premature abandonment of similar fields. The Unit was a mature waterflood with water cut exceeding 95%. Oil must be mobilized through the use of a miscible or near-miscible fluid to recover significant additional reserves. Also, because the unit was relatively small, it did not have the benefit of economies of scale inherent in normal larger scale projects. Thus, new and innovative methods were required to reduce investment and operating costs. Two primary methods used to accomplish improved economics were use of reservoir characterization to restrict the flood to the higher quality rock in the unit and use of horizontal injection wells to cut investment and operating costs. The project consisted of two budget phases. Budget Phase I started in June 1994 and ended late June 1996. In this phase Reservoir Analysis, Characterization Tasks and Advanced Technology Definition Tasks were completed. Completion enabled the project to be designed, evaluated, and an Authority for Expenditure (AFE) for project implementation submitted to working interest owners for approval. Budget Phase II consisted of the implementation and execution of the project in the field. Phase II was completed in July 2001. Performance monitoring, during Phase II, by mid 1998 identified the majority of producing wells which under performed their anticipated withdrawal rates. Newly drilled and re-activated wells had lower offtake rates than originally forecasted. As a result of poor offtake, higher reservoir pressure was a concern for the project as it limited CO{sub 2} injectivity. To reduce voidage balance, and reservoir pressure, a disposal well was therefore drilled. Several injection surveys indicated the CO{sub 2} injection wells had severe conformance issues. After close monitoring of the project to the end of 1999, it was evident the project would not recover the anticipated tertiary reserves. The main reasons for under-performance were poor in zone CO{sub 2} injection into the upper San Andres layers, poorer offtake rates from newly drilled replacement wells and a higher than required reservoir pressure. After discussion internally within Phillips, externally with the Department of Energy (DOE) and SCU partners, a redevelopment of South Cowden was agreed upon to commence in year 2000. The redevelopment essentially abandoned the original development for Budget Phase II in favor of a revised approach. This involved conformance techniques to resolve out of zone CO{sub 2} injection and use of horizontal wells to improve in zone injectivity and productivity. A phased approach was used to ensure short radius lateral drilling could be implemented effectively at South Cowden. This involved monitoring drilling operations and then production response to determine if larger investments during the second phase were justified. Redevelopment Phase 1 was completed in May 2000. It was deemed a success in regard to finding suitable/cost-effective technology for drilling horizontal laterals and finding a technique that could sustain long-term productivity from the upper layers of the San Andres reservoir. Four existing vertical producing wells were isolated from their existing completions and sidetracked with horizontal laterals into the upper layers of the San Andres. Overall average offtake rates for the four wells increased by a factor of 12 during the first four months after completion of Phase 1. Phase 2 of the redevelopment focused on current CO{sub 2} vertical injection wells. Techniques were applied to resolve near well conformance concerns and then either single or dual laterals were dril

K.J. Harpole; Ed G. Durrett; Susan Snow; J.S. Bles; Carlon Robertson; C.D. Caldwell; D.J. Harms; R.L. King; B.A. Baldwin; D. Wegener; M. Navarrette

2002-09-01T23:59:59.000Z

152

Coorelations for cresting behavior in horizontal wells. Quarterly report, October 1, 1996--December 31, 1996  

SciTech Connect

The following activities have been carried out in the last three months. (1) The fourth review meeting of the Horizontal Well Industrial Affiliates Program was held on October 10-11 at Stanford. The meeting was well attended and well received. In addition to the project presentations, a number of member presentations were also made at the meeting. (2) Draft plans for the continuation of the two-phase flow experiments were drawn up and sent to Marathon and other members for their review and comments. Series of new experiments with and without the wire wrapped screens used in 1996 are being considered for 1997. (3) Work on the application of horizontal wells for producing gas condensate reservoirs was continued. After verification of the black oil formulation, emphasis is being put on the compositional case where simulation runs have been set up to check the results against a semi-analytical solution. (4) The previous work on the effects of heterogeneities on horizontal well performance was continued and a paper on the subject was completed. Future work in this area will deal with a careful analysis of the interaction of heterogeneity and production performance. (5) Research work on developing coarse grid methods to study cresting in horizontal wells was continued. The previous correlations for optimum grid size, breakthrough time, and post breakthrough behavior (i.e., water-oil ratio) were further tested and optimized. Procedures to derive pseudo-functions either using numerical correlations or coarse grid simulations have been proposed and successfully tested.

Aziz, K.; Hewett, T.A.

1996-12-31T23:59:59.000Z

153

Integrated approach towards the application of horizontal wells to improve waterflooding performance. Quarterly report, January 1--March 31, 1997  

SciTech Connect

The overall purpose of the proposed project is to improve secondary recovery performance of a marginal oil field through the use of an appropriate reservoir management plan. The selection of plan will be based on the detailed reservoir description using an integrated approach. The authors expect that 2 to 5% of the original oil in place will be recovered using this method. This should extend the life of the reservoir by at least 10 years. The project is divided into two stages. In Stage 1 of the project, the authors selected part of the Glenn Pool Field-Self Unit. They conducted cross borehole tomography surveys and formation micro scanner logs through a newly drilled well. By combining the state-of-the-art data with conventional core and log data, they developed a detailed reservoir description based on an integrated approach. After conducting extensive reservoir simulation studies, they evaluated alternate reservoir management strategies to improve the reservoir performance including drilling of a horizontal injection well. They observed that selective completion of many wells followed by an increase in the injection rate was the most feasible option to improve the performance of the Self Unit. This management plan is currently being implemented and the performance is being monitored. Stage 2 of the project will involve selection of part of the same reservoir (Berryhill Unit-Tract 7), development of reservoir description using only conventional data, simulation of flow performance using developed reservoir description, selection of an appropriate reservoir management plan, and implementation of the plan followed by monitoring of reservoir performance.

Kelkar, M.; Liner, C.; Kerr, D.

1997-10-01T23:59:59.000Z

154

Crump Geyser: High Precision Geophysics & Detailed Structural Exploration & Slim Well Drilling  

Energy.gov (U.S. Department of Energy (DOE))

DOE Geothermal Peer Review 2010 - Presentation. Project objectives: Discover new 260F and 300F geothermal reservoirs in Oregon. To demonstrate the application of high precision geophysics for well targeting. Demonstrate a combined testing approach to Flowing Differential Self Potential (FDSP) and electrical tomography resistivity as a guide to exploration and development. Demonstrate utility and benefits of sump-less drilling for a low environmental impact. Create both short and long term employment through exploration, accelerated development timeline and operation.

155

Development of general inflow performance relationships (IPR's) for slanted and horizontal wells producing heterogeneous solution-gas drive reservoirs  

SciTech Connect

Since 1968, the Vogel equation has been used extensively and successfully for analyzing the inflow performance relationship (IPR) of flowing vertical wells producing by solution-gas drive. Oil well productivity can be rapidly estimated by using the Vogel IPR curve and well outflow performance. With recent interests on horizontal well technology, several empirical IPRs for solution-gas drive horizontal and slanted wells have been developed under homogeneous reservoir conditions. This report presents the development of IPRs for horizontal and slanted wells by using a special vertical/horizontal/slanted well reservoir simulator under six different reservoir and well parameters: ratio of vertical to horizontal permeability, wellbore eccentricity, stratification, perforated length, formation thickness, and heterogeneous permeability. The pressure and gas saturation distributions around the wellbore are examined. The fundamental physical behavior of inflow performance for horizontal wells is described.

Cheng, A.M.

1992-04-01T23:59:59.000Z

156

Analysis of wellbore instability in vertical, directional, and horizontal wells using field data  

E-Print Network (OSTI)

Analysis of wellbore instability in vertical, directional, and horizontal wells using field data M.A-mail addresses: mamuddin@kfupm.edu.sa (M.A. Mohiuddin), aazeez@kfupm.edu.sa (A. Abdulraheem). 0920-4105/$ - see. Mohiuddin, K. Khan, A. Abdulraheem , A. Al-Majed, M.R. Awal Center for Petroleum and Minerals, Research

Al-Majed, Abdulaziz Abdullah

157

Productivity and injectivity of horizontal wells. Quarterly report, July 1, 1993--September 30, 1993  

SciTech Connect

A number of research activities have been carried out in the last three months. A list outlining these efforts is presented below followed by brief description of each activity in the subsequent sections of this report: (1) The available analytical solutions in the literature for steady state critical rates of horizontal wells are examined. Application of these methods to a cresting example show significant uncertainties in prediction of critical rates. (2) Sensitivity computations have been run for evaluating the effects of shale distribution on the performance of horizontal wells in heterogeneous reservoirs. (3) A number of single phase (water and oil) and two-phase (water and air) experiments have been completed in the Marathon Wellbore Model and the collected data are being analyzed. (4) A presentation of our project was given in the International Technology Forum DEA-44/67 on Horizontal, Slimhole, and Coiled Tubing, held by Maurer. (5) Our draft review report entitled ``Opportunities for Horizontal Wells and Problems in Predicting Their Performance`` has been completed.

Fayers, F.J.; Aziz, K.; Hewett, T.A.

1993-12-01T23:59:59.000Z

158

DEVELOPMENT OF GLASS AND GLASS CERAMIC PROPPANTS FROM GAS SHALE WELL DRILL CUTTINGS  

SciTech Connect

The objective of this study was to develop a method of converting drill cuttings from gas shale wells into high strength proppants via flame spheroidization and devitrification processing. Conversion of drill cuttings to spherical particles was only possible for small particle sizes (< 53 {micro}m) using a flame former after a homogenizing melting step. This size limitation is likely to be impractical for application as conventional proppants due to particle packing characteristics. In an attempt to overcome the particle size limitation, sodium and calcium were added to the drill cuttings to act as fluxes during the spheroidization process. However, the flame former remained unable to form spheres from the fluxed material at the relatively large diameters (0.5 - 2 mm) targeted for proppants. For future work, the flame former could be modified to operate at higher temperature or longer residence time in order to produce larger, spherical materials. Post spheroidization heat treatments should be investigated to tailor the final phase assemblage for high strength and sufficient chemical durability.

Johnson, F.; Fox, K.

2013-10-02T23:59:59.000Z

159

Productivity and injectivity of horizontal wells. Annual report for the period, March 10, 1994--March 9, 1995  

SciTech Connect

Contents of this annual report include the following: (1) detailed well model for reservoir simulation--task 1; (2) comparative aspects of coning behavior in vertical and horizontal wells--task 1; (3) skin factor calculations for vertical, deviated, and horizontal wells--task 2; (4) a dissipation-based coarse grid system and its application to the scaleup of two phase problems--tasks 2 and 4; (5) analyses of experiments at Marathon Oil Company--task 3; (6) development of mechanistic model for multiphase flow in horizontal wells--task 3; and (7) sensitivity studies of wellbore friction and inflow for a horizontal well--task 8.

Fayers, F.J.

1995-07-01T23:59:59.000Z

160

Status Report A Review of Slimhole Drilling  

SciTech Connect

This 1994 report reviews the various applications of slimhole technology including for exploration in remote areas, low-cost development wells, reentering existing wells, and horizontal and multilateral drilling. Advantages of slimholes to regular holes are presented. Limitations and disadvantages of slimholes are also discussed. In 1994, slimhole drilling was still an ongoing development technology. (DJE 2005)

Zhu, Tao; Carroll, Herbert B.

1994-09-01T23:59:59.000Z

Note: This page contains sample records for the topic "horizontal wells drilling" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


161

A Parametric Study on the Benefits of Drilling Multilateral and Horizontal Wells in  

E-Print Network (OSTI)

, Texas SPE Paper # 96018 #12;- Coal is an unusual reservoir rock, with highly complex reservoir;The Model - A dual-porosity, homogeneous reservoir model with Cartesian grid system. - Model Reservoirs Nikola Maricic, Chevron Shahab D. Mohaghegh, WVU Emre Artun, WVU October 12, 2005 ATCE 2005 Dallas

Mohaghegh, Shahab

162

Shallow oil production using horizontal wells with enhanced oil recovery techniques  

SciTech Connect

Millions of barrels of oil exist in the Bartlesville formation throughout Oklahoma, Kansas, and Missouri. In an attempt to demonstrate that these shallow heavy oil deposits can be recovered, a field project was undertaken to determine the effectiveness of enhanced oil recovery techniques (EOR) employing horizontal wells. Process screening results suggested that thermal EOR processes were best suited for the recovery of this heavy oil. Screening criteria suggested that in situ combustion was a viable technique for the production of these reserves. Laboratory combustion tube tests confirmed that sufficient amounts of fuel could be deposited. The results of the in situ combustion field pilot were disappointing. A total overall recovery efficiency of only 16.0 percent was achieved. Results suggest that the combustion front might have moved past the horizontal well, however elevated temperatures or crude upgrading were not observed. Factors contributing to the lack of production are also discussed.

Satchwell, R.M.; Johnson, L.A. Jr. [Western Research Institute, Laramie, WY (United States); Trent, R. [Univ. of Alaska, Fairbanks, AK (United States)

1995-02-01T23:59:59.000Z

163

A Novel Approach to Modeling and Simulating of Underbalanced Drilling Process in Oil and Gas Wells  

Science Journals Connector (OSTI)

This paper presents an advanced dynamic model and computer simulator for underbalanced drilling. The model is formulated based on the ... theory of multiphase transient flow referring to the drilling mud, water,

Jun Fan; Xi-an Wang; Song Han; Zhong-shen Yu

2009-01-01T23:59:59.000Z

164

Laboratory evaluation of filtercake cleanup techniques and metallic-screens plugging mechanisms in horizontal wells  

E-Print Network (OSTI)

Tests were conducted to evaluate the plugging mechanisms of metallic screens after cleaning up the altercate developed on an unconsolidated core by two exiting drill-in fluids (DIF's). Two simulated drill solids, clay or 75-[]m reservoir sand were...

Garcia Orrego, Gloria Stella

1999-01-01T23:59:59.000Z

165

Predicted and actual productions of horizontal wells in heavy-oil fields  

Science Journals Connector (OSTI)

This paper discusses the comparison of predicted and actual cumulative and daily oil production. The predicted results were obtained from the use of Joshi's equation, wherein, the effects of anisotropy and eccentricity were included. The cumulative production obtained from the use of equations developed by Borisov, Giger, Renard and Dupuy resulted in errors in excess of 100%, thus, they were not considered applicable for predicting cumulative and daily flows of heavy oils in horizontal wells. The wells considered in this analysis varied from 537 to 1201 metres with corresponding well bores of 0.089 to. 0.110 m. Using Joshi's equation, the predicted cumulative oil-production was within a 20% difference for up to 12 months of production for long wells and up to 24 months for short wells. Short wells were defined as those being under 1000 m.

Peter Catania

2000-01-01T23:59:59.000Z

166

Mixed Integer Model Predictive Control of Multiple Shale Gas Wells.  

E-Print Network (OSTI)

?? Horizontal wells with multistage hydraulic fracturing are today the most important drilling technology for shale gas extraction. Considered unprofitable before, the production has now… (more)

Nordsveen, Espen T

2012-01-01T23:59:59.000Z

167

Well testing model for multi-fractured horizontal well for shale gas reservoirs with consideration of dual diffusion in matrix  

Science Journals Connector (OSTI)

Abstract Shale gas reservoir is typical unconventional reservoir, it's necessary to take advantage of multi-stage fractured horizontal well so as to develop those kinds of reservoirs, which can form high conductivity hydraulic fractures and activate natural fractures. Due to the existence of concentration gap between matrix and fractures, desorption gas can simultaneously diffuse into the natural fractures and hydraulic fractures. This process can be called dual diffusion. Based on the triple-porosity cubic model, this paper establishes a new well testing model of multi-stage fractured horizontal well in shale gas reservoir with consideration of the unique mechanisms of desorption and dual diffusion in matrix. Laplace transformation is employed to solve this new model. The pseudo pressure transient responses are inverted into real time space with stehfest numerical inversion algorithm. Type curves are plotted, and different flow regimes in shale gas reservoirs are identified and the effects of relevant parameters are analyzed as well. Considering the mechanism of dual diffusion in matrix, the flow can be divided into five regimes: early linear flow; pseudo-steady state inter-porosity flow; the diffusion from matrix into micro-fractures; the diffusion from matrix into hydraulic fractures and boundary-dominated flow. There are large distinctions of pressure response between pseudo steady state diffusion and unsteady state diffusion under different value of pore volume ratio. It's similar to the feature of pseudo-steady state inter-porosity flow, diffusion coefficient and Langmuir parameters reflect the characters of pseudo-steady state diffusion. The numbers of stage of hydraulic fractures have certain impact on the shape factor of matrix and the inter-porosity coefficient. This new model is validated compared with some existing models. Finally, coupled with an application, this mew model can be approximately reliable and make some more precise productivity prediction.

Leng Tian; Cong Xiao; Mingjin Liu; Daihong Gu; Guangyu Song; Helong Cao; Xianglong Li

2014-01-01T23:59:59.000Z

168

Measurement-while-drilling (MWD) development for air drilling  

SciTech Connect

The objective of this program is to tool-harden and make commercially available an existing wireless MWD tool to reliably operate in an air, air-mist, or air-foam environment during Appalachian Basin oil and gas directional drilling operations in conjunction with downhole motors and/or (other) bottom-hole assemblies. The application of this technology is required for drilling high angle (holes) and horizontal well drilling in low-pressure, water sensitive, tight gas formations that require air, air-mist, and foam drilling fluids. The basic approach to accomplishing this objective was to modify GEC`s existing electromagnetic (e-m) ``CABLELESS``{trademark} MWD tool to improve its reliability in air drilling by increasing its tolerance to higher vibration and shock levels (hardening). Another important aim of the program is to provide for continuing availability of the resultant tool for use on DOE-sponsored, and other, air-drilling programs.

Rubin, L.A.; Harrison, W.H.

1992-06-01T23:59:59.000Z

169

Mathematical modeling of thixotropic drilling mud and crude oil flow in wells and pipelines—A review  

Science Journals Connector (OSTI)

Many drilling muds and crude oils are known to be thixotropic. Under a wide range of pressures, temperatures and flow regimes, they display unusual complex flow properties when flowing through wells (crude oils and drilling muds) and during storage and pipeline transportation (crude oils). Understanding and modeling the deviation from Newtonian behavior of drilling muds and crude oils are essential in accurately and optimally designing the flow systems associated with these fluids. Despite an impressive amount of experimental and rheological modeling studies concerning the non-Newtonian drilling mud and crude oil behavior, mathematical modeling studies taking into account their thixotropic properties are rare. In addition, there was no literature review of the knowledge gained to date. Thus, a review paper on studies addressing the mathematical modeling of thixotropic drilling mud and crude oil flow in wells and pipelines will pinpoint the challenges and limitations encountered in such studies. This will hopefully trigger further development and new research topics. This review paper focuses mainly on mathematical modeling studies concerning the well and pipeline flow of thixotropic drilling muds and crude oils. After describing how thixotropy is understood today inside and outside of the petroleum industry community, several mathematical models available in the literature are examined. Finally, challenges, limitations, and potential areas for the development of these models are presented.

S. Livescu

2012-01-01T23:59:59.000Z

170

Horizontal drilling in the Bakken Formation - The hunt for an elephant that never left the source system  

SciTech Connect

New organic-geochemical studies show that bitumen extracted from the upper and lower shale members of the Mississippian Madison Group oils, and that the Bakken shales have contributed only a minor percentage of the conventionally produced oil in the Williston basin. Instead, organic-rich madison marls are an adequate source for the Madison oils. Also, few pathways exist for vertical migration of Bakken-generated oil to shallower Madison reservoirs. Vertical wells in older Bakken oil pools are perforated in one or all of the three units adjacent to the two Bakken shales but are not necessarily perforated in the Bakken shales. Rock-Eval analyses of 6- to 12-in. spaced core samples show that where Bakken shales are thermally mature, the three adjacent organic-poor units contain 10-20 times the hydrocarbons (HCs) they could have generated. Thus, Bakken-generated HCs appear to have moved into the three adjacent units, probably via fractures created by volume expansion of organic matter during HC generation in the Bakken shales. Bakken well histories reveal that unsuccessful Bakken wells appear due to questionable techniques during these operations and not a lack of fractures. If a large in-place resource base exists in the Bakken source system, its commercial recovery will depend on new exploration, drilling, completion, and production technologies and on how much of the generated oil is in fractures rather than dispersed throughout the rocks.

Price, L. (Geological Survey, Denver, CO (United States)); Le Fever, J. (North Dakota Geological Survey, Grand Forks (United States))

1991-06-01T23:59:59.000Z

171

StarWars Laser Technology Applied to Drilling and Completing Gas Wells  

NLE Websites -- All DOE Office Websites (Extended Search)

u' m .,. . Society of Petroleum Engineers u I SPE 49259 StarWars Laser Technology Applied to Drilling and Completing Gas Wells R.M. Graves, SPE, Colorado School of Mines; and D.G. O'Brien, PE, SPE, Solutions Engineering Copyr@ht 1998, Scdety of Petroleum Engineers, Inc. This paper was prapared for presentation at the 1998 SPE Annual Technicar Conference and Exhibition bald in New Orteans, Lcuisiana, 27-30 September 1998, This paper waa selected for presentation by en SPE Program Commiftee folrowing review of information contained in an abstract submitted by the author(a). Contents of the paper, as prasented, have not been reviewed by the Society of Petroleum Engineers and are subject to correction by the author(s). The materiar, as presented, does not necessarily reflect any position of the .%ciety of Petroleum Engineers, its officers, or members. Papers prasented at SPE meetings

172

Integrated analysis of production potential and profitability of a horizontal well in the Lower Glen Rose Formation, Maverick County, Texas  

SciTech Connect

The U.S. Department of Energy/Morgantown Energy Technology Center (DOE/METC) awarded a contract in 1991 to Prime Energy Corporation (PEC) to demonstrate the benefit of using horizontal wells to recover gas from low permeability formations. The project area was located in the Chittim field of Maverick County, Texas. The Lower Glen Rose Formation in the Chittim field was a promising horizontal well candidate based on the heterogenous nature of the reservoir (suggested by large well-to-well variances in reserves) and the low percentage of economical vertical wells. Since there was substantial evidence of reservoir heterogeneity, it was unknown whether the selected, wellsite would penetrate a reservoir with the desired properties for a horizontal well. Thus, an integrated team was formed to combine geologic analysis, seismic interpretation, reservoir engineering, reservoir simulation, and economic assessment to analyze the production potential and profitability of completing a horizontal well in the Lower Glen Rose formation.

Ammer, J.R.; Mroz, T.H.; Zammerilli, A.M.; Yost, A.B. II [Dept. of Energy, Morgantown, WV (United States); Muncey, J.G.; Hegeman, P.S.

1995-03-01T23:59:59.000Z

173

McGinness Hills Well 27A-10 Daily Drilling Report Data  

SciTech Connect

This data should be used with the daily drilling record and other data which can be obtained from the contact listed below

Knudsen, Steven

2014-03-25T23:59:59.000Z

174

McGinness Hills Well 27A-10 Daily Drilling Report Data  

DOE Data Explorer (OSTI)

This data should be used with the daily drilling record and other data which can be obtained from the contact listed below

Knudsen, Steven

175

State-of-the-art in coalbed methane drilling fluids  

SciTech Connect

The production of methane from wet coalbeds is often associated with the production of significant amounts of water. While producing water is necessary to desorb the methane from the coal, the damage from the drilling fluids used is difficult to assess, because the gas production follows weeks to months after the well is drilled. Commonly asked questions include the following: What are the important parameters for drilling an organic reservoir rock that is both the source and the trap for the methane? Has the drilling fluid affected the gas production? Are the cleats plugged? Does the 'filtercake' have an impact on the flow of water and gas? Are stimulation techniques compatible with the drilling fluids used? This paper describes the development of a unique drilling fluid to drill coalbed methane wells with a special emphasis on horizontal applications. The fluid design incorporates products to match the delicate surface chemistry on the coal, a matting system to provide both borehole stability and minimize fluid losses to the cleats, and a breaker method of removing the matting system once drilling is completed. This paper also discusses how coal geology impacts drilling planning, drilling practices, the choice of drilling fluid, and completion/stimulation techniques for Upper Cretaceous Mannville-type coals drilled within the Western Canadian Sedimentary Basin. A focus on horizontal coalbed methane (CBM) wells is presented. Field results from three horizontal wells are discussed, two of which were drilled with the new drilling fluid system. The wells demonstrated exceptional stability in coal for lengths to 1000 m, controlled drilling rates and ease of running slotted liners. Methods for, and results of, placing the breaker in the horizontal wells are covered in depth.

Baltoiu, L.V.; Warren, B.K.; Natras, T.A.

2008-09-15T23:59:59.000Z

176

Comparison of revegetation of a gas pipeline right-of-way in two forested wetland crossings involving conventional methods of pipeline installation and horizontal drilling, Nassau County, Florida  

SciTech Connect

One year after pipeline installation, vegetation in the right-of-way (ROW) was inventoried at two stream floodplain crossings in Nassau County, Florida. Both sites were forested wetlands composed of Acer rubrum, Fraxinus caroliniana, Liquidamber styraciflua, Nyssa ogecho, Quercus laurifolia, and Taxodium distichum, together with other wetland trees. Pipeline installation across the Brandy Branch floodplain was by conventional ditching and backfill methods. Installation across the Deep Creek floodplain was by horizontal drilling after clearcutting the ROW. The latter method left tree stumps, understory vegetation, and soil layers intact, except for disruptions caused by logging. According to the inventory, vegetation at the drilled site was more diverse (nearly twice as many species occurring in the ROW as at the trenched site) and more robust (no unvegetated exposed soil compared to 15% at the trenched site). Differences between the ROW vegetation at the two sites can be attributed to both site differences and installation technologies used.

Van Dyke, G.D. [Trinity Christian Coll., Palos Heights, IL (United States). Dept. of Biology; Shem, L.M.; Zimmerman, R.E. [Argonne National Lab., IL (United States)

1993-10-01T23:59:59.000Z

177

Determining circulating fluid temperature in drilling, workover, and well-control operations  

SciTech Connect

Estimation of fluid temperature in both flow conduits (drillpipe or tubing and the annulus) is required to ascertain the fluid density and viscosity and, in turn, to calculate the pressure drop or the maximum allowable pumping rate for a number of operations. These operations include drilling, workover, and well control. The fluid temperature estimation becomes critical for high-temperature or geothermal reservoirs where significant heat exchange occurs or when fluid properties are temperature sensitive, such as for a non-Newtonian fluid. In this work, the authors present an analytical model for the flowing fluid temperature in the drillpipe/tubing and in the annulus as a function of well depth and circulation time. The model is based on an energy balance between the formation and the fluid in the drillpipe.tubing and annulus. Steady-state heat transfer is assumed in the wellbore while transient heat transfer takes place in the formation. solutions are obtained for two possible scenarios: (1) the fluid flows down the annulus and up the drillpipe/tubing, and (2) the fluid flows down the tubing and up the annulus. The analytic model developed is cast in a set of simple algebraic equations for rapid implementation. The authors also show that the maximum temperature occurs not at the well bottom, but at some distance higher from the bottom for flow up the annulus.

Kabir, C.S. [Chevron Overseas Petroleum Technology Co. (Kuwait); Hasan, A.R.; Ameen, M.M. [Univ. of North Dakota, Grand Forks, ND (United States); Kouba, G.E.

1996-06-01T23:59:59.000Z

178

ENOC 2014, July 6-11, 2014, Vienna, Austria Numerical study of the nonlinear dynamics of horizontal drillings  

E-Print Network (OSTI)

as a first effort to solve a robust optimization problem, which seeks to maximize the rate of penetration to maximize the rate of penetration of the column into the soil (to reduce the drilling process costs) [3

Paris-Sud XI, Université de

179

Synthesis and Evaluation of a New Cationic Surfactant for Oil-Well Drilling Fluid  

Science Journals Connector (OSTI)

A new additive cationic surfactant for drilling fluid was synthesized by alkylation of coal ... results when utilized in the formulation of both oil-based mud and synthetic-based mud as...

Soad A. Mahmoud; Mona M. Dardir

2011-01-01T23:59:59.000Z

180

Sustainable Development of the Shale Gas Supply Chain and the Optimal Drilling Strategy for Nonconventional Wells  

Science Journals Connector (OSTI)

Abstract We present a long-term MINLP planning model for the development of shale gas fields. A key decision is the drilling/fracturing strategy yielding the freshwater consumption profile, which is critical in waterscarce regions with high cumulative demand for water. Results show that the model can help companies to reduce freshwater consumption by optimally planning drilling operations, at the expense of small reductions in the net present value of the projects.

Diego C. Cafaro; Ignacio E. Grossmann

2014-01-01T23:59:59.000Z

Note: This page contains sample records for the topic "horizontal wells drilling" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


181

Detecting and assessing hydrocarbon reservoirs without the need to drill test wells is of major importance to the petro-  

E-Print Network (OSTI)

Detecting and assessing hydrocarbon reservoirs without the need to drill test wells is of major survey was carried out from the research ship RRS Charles Darwin offshore Angola, in an area with proven., 2000; Ellingsrud et al., 2001), could direct detect hydrocarbon-filled layers in the subseafloor

Constable, Steve

182

Development and application of type curves for pressure transient analysis of horizontal wells in shale gas reservoirs  

Science Journals Connector (OSTI)

Even though significant progresses have been made in the past few years, there appears to be a lack of information regarding the characterisation of shale gas formations. A major purpose of this study is to demonstrate impacts of horizontal well geometries and gas flow parameters as well as shale gas reservoir system on horizontal well production behaviour and flow regime on pressure transient analysis (PTA). Extensive numerical simulations were conducted to model transient pressure behaviour of a horizontal well and apply the results to well test analysis in shale gas reservoirs. Based on the results from numerical simulations, a set of type curves have been developed in terms of dimensionless pseudopressure and time. Results from type curve matching for synthetic pressure data in shale gas reservoirs demonstrate that the conventional analysis approach may still be applicable for the quantitative analysis on the transient gas flow behaviour and determination of formation properties. [Received: June 21, 2013; Accepted: August 6, 2013

Sung Jun Lee; Tae Hong Kim; Kun Sang Lee

2014-01-01T23:59:59.000Z

183

Detection of water or gas entry into horizontal wells by using permanent downhole monitoring systems  

E-Print Network (OSTI)

because geothermal temperature differences in depth make the wellbore temperature sensitive to the amount and the type of fluids flowing in the wellbore. Geothermal temperature does not change, however, along a horizontal wellbore, which leads to small...

Yoshioka, Keita

2007-09-17T23:59:59.000Z

184

Development of general inflow performance relationships (IPR`s) for slanted and horizontal wells producing heterogeneous solution-gas drive reservoirs  

SciTech Connect

Since 1968, the Vogel equation has been used extensively and successfully for analyzing the inflow performance relationship (IPR) of flowing vertical wells producing by solution-gas drive. Oil well productivity can be rapidly estimated by using the Vogel IPR curve and well outflow performance. With recent interests on horizontal well technology, several empirical IPRs for solution-gas drive horizontal and slanted wells have been developed under homogeneous reservoir conditions. This report presents the development of IPRs for horizontal and slanted wells by using a special vertical/horizontal/slanted well reservoir simulator under six different reservoir and well parameters: ratio of vertical to horizontal permeability, wellbore eccentricity, stratification, perforated length, formation thickness, and heterogeneous permeability. The pressure and gas saturation distributions around the wellbore are examined. The fundamental physical behavior of inflow performance for horizontal wells is described.

Cheng, A.M.

1992-04-01T23:59:59.000Z

185

Analytical and semi-analytical solutions of horizontal well capture times under no-ow and constant-head boundaries  

E-Print Network (OSTI)

for oil and gas production in the past decade [15,21]. Extensive studies on pressure anal- ysis with surface restrictions (e.g., land®lls, lagoons, buildings, wetlands, lakes, utility lines, tanks), (2 organic contaminants. Fluid and gas ¯ows to a horizontal well or trench have been studied before. An early

Zhan, Hongbin

186

Economic Impact of Reservoir Properties, Horizontal Well Length and Orientation on Production from Shale Formations: Application to New  

E-Print Network (OSTI)

SPE 125893 Economic Impact of Reservoir Properties, Horizontal Well Length and Orientation production. Economic analyses are performed to identify and rank the impact of the above parameters. (3) The lack of dense natural fractures does not eliminate the potential for an economic fracture

Mohaghegh, Shahab

187

Black Warrior: Sub-soil gas and fluid inclusion exploration and slim well drilling  

Energy.gov (U.S. Department of Energy (DOE))

DOE Geothermal Peer Review 2010 - Presentation. Project Objectives: Discover a blind, low-moderate temperature resource: Apply a combination of detailed sub-soil gas, hydrocarbon, and isotope data to define possible upflow areas; Calibrate the sub-soil chemistry with down-hole fluid inclusion stratigraphy and fluid analyses to define a follow-up exploration drilling target; Create short term jobs and long term employment through resource exploration, development and power plant operation; Extend and adapt the DOE sub-soil 2 meter probe technology to gas sampling.

188

Offshore and shipping activities in the Norwegian Arctic areas: The environmental dimension: Case: Norsk Hydro's drilling of well 7316/5-1, autumn 1992  

Science Journals Connector (OSTI)

This paper describes how Norsk Hydro planned and executed the safety, environment and emergency preparedness matters related to the exploration drilling of well 7316/5-1, the most northern well drilled on the Norwegian continental shelf. This well (1992) was Norsk Hydro's first experience with the new above-mentioned regulations. For later wells, Norsk Hydro developed both how to use and implement these new regulations.

Magne Thomassen

1994-01-01T23:59:59.000Z

189

Reverse trade mission on the drilling and completion of geothermal wells  

SciTech Connect

This draft report was prepared as required by Task No. 2 of the US Department of Energy, Grant No. DE-FG07-89ID12850 Reverse Trade Mission to Acquaint International Representatives with US Power Plant and Drilling Technology'' (mission). As described in the grant proposal, this report covers the reactions of attendees toward US technology, its possible use in their countries, and an evaluation of the mission by the staff leaders. Note this is the draft report of one of two missions carried out under the same contract number. Because of the diversity of the mission subjects and the different attendees at each, a separate report for each mission has been prepared. This draft report has been sent to all mission attendees, specific persons in the US Department of Energy and Los Alamos National Lab., the California Energy Commission (CEC), and various other governmental agencies.

Not Available

1989-09-09T23:59:59.000Z

190

An Analytical Model for Simulating Heavy-Oil Recovery by Cyclic Steam Injection Using Horizontal Wells, SUPRI TR-118  

SciTech Connect

In this investigation, existing analytical models for cyclic steam injection and oil recovery are reviewed and a new model is proposed that is applicable to horizontal wells. A new flow equation is developed for oil production during cyclic steaming of horizontal wells. The model accounts for the gravity-drainage of oil along the steam-oil interface and through the steam zone. Oil viscosity, effective permeability, geometry of the heated zone, porosity, mobile oil saturation, and thermal diffusivity of the reservoir influence the flow rate of oil in the model. The change in reservoir temperature with time is also modeled, and it results in the expected decline in oil production rate during the production cycle as the reservoir cools. Wherever appropriate, correlations and incorporated to minimize data requirements. A limited comparison to numerical simulation results agrees well, indicating that essential physics are successfully captured. Cyclic steaming appears to be a systematic met hod for heating a cold reservoir provided that a relatively uniform distribution of steam is obtained along the horizontal well during injection. A sensitivity analysis shows that the process is robust over the range of expected physical parameters.

Diwan, Utpal; Kovscek, Anthony R.

1999-08-09T23:59:59.000Z

191

Optimising the reward of appraisal drilling  

SciTech Connect

Management of the uncertainties associated with the development of a hydrocarbon resource is essential to minimize economic risk. In many instances these uncertainties can only be reduced by appraisal drilling. This presentation illustrates the efforts being made to manage uncertainty by determining its impact on overall project profitability. The Value of Information (VOI) approach is described. VOI aims at quantifying the benefits of appraisal by determining its economic reward in terms of its contribution to a development plan which is economically robust over the uncertainty range. Appraisal drilling costs can be reduced by combining appraisal and development objectives in one well. The growing use of horizontal drilling technology has resulted in novel approaches to appraisal. As examples, in the Osprey and Brent Fields (UK North Sea) wells were designed to satisfy both appraisal and development objectives. In Osprey, a well was drilled from a central production platform to provide water injection support in a satellite structure while at the same time appraising the saddle area between the two structures. In Brent, horizontal wells are used to appraise and develop the so called slump blocks, characterized by being highly faulted and compartmentalized. Another increasingly common application of horizontal wells is for the flank appraisal of hydrocarbon bearing structure. Examples from the Rabi Field (Gabon) and Batan Field (Nigeria) show how appraisal was achieved by extending the reach of horizontal development wells from the central core of the structures.

Gdula, J.

1996-12-31T23:59:59.000Z

192

Optimising the reward of appraisal drilling  

SciTech Connect

Management of the uncertainties associated with the development of a hydrocarbon resource is essential to minimize economic risk. In many instances these uncertainties can only be reduced by appraisal drilling. This presentation illustrates the efforts being made to manage uncertainty by determining its impact on overall project profitability. The Value of Information (VOI) approach is described. VOI aims at quantifying the benefits of appraisal by determining its economic reward in terms of its contribution to a development plan which is economically robust over the uncertainty range. Appraisal drilling costs can be reduced by combining appraisal and development objectives in one well. The growing use of horizontal drilling technology has resulted in novel approaches to appraisal. As examples, in the Osprey and Brent Fields (UK North Sea) wells were designed to satisfy both appraisal and development objectives. In Osprey, a well was drilled from a central production platform to provide water injection support in a satellite structure while at the same time appraising the saddle area between the two structures. In Brent, horizontal wells are used to appraise and develop the so called slump blocks, characterized by being highly faulted and compartmentalized. Another increasingly common application of horizontal wells is for the flank appraisal of hydrocarbon bearing structure. Examples from the Rabi Field (Gabon) and Batan Field (Nigeria) show how appraisal was achieved by extending the reach of horizontal development wells from the central core of the structures.

Gdula, J.

1996-01-01T23:59:59.000Z

193

Effects of oil and gas well-drilling fluids on the biomass and community structure of microbiota that colonize sands in running seawater  

Science Journals Connector (OSTI)

Well-drilling fluid and a number of the known components (barite, clay, Aldacide®, Surflo®, and Dowicide®, were tested for effects on the biomass and community structure of the microbiota that colonize marine san...

Glen A. Smith; Janet S. Nickels…

1982-01-01T23:59:59.000Z

194

Improved sweep efficiency through the application of horizontal well technology in a mature combustion EOR project: Battrum Field, Saskatchewan, Canada  

SciTech Connect

In-situ combustion has been employed in the Battrum field since 1964. Although the field has responded favorably to combustion, efficiency of the horizontal displacement process appears to be poor in some areas of the field. Injected air and combustion gases accumulate at the top of the reservoir, and injected water moves into a zone of relatively high mobile water saturation, occurring at the base of the reservoir. Rapid breakthrough of the injected fluids increases operating costs due to high gas-oil ratios. Placement of horizontal wells below the combustion gas cap, and conversion to a vertical displacement process is expected to increase oil rate, improve oil recovery, and reduce operating costs.

Ames, B.G.; Grams, R.E.; Pebdani, F.N. [Mobil Oil Canada, Alberta (Canada)

1995-02-01T23:59:59.000Z

195

Bachaquero-01 reservoir, Venezuela-increasing oil production by switching from cyclic steam injection to steamflooding using horizontal wells  

E-Print Network (OSTI)

, existing and two new vertical producers): schematic diagrams showing grid dimensions, well locations and completion intervals. . . . . 106 XVI F1GURE Page 5. 20 Area LL3343, Case 4 (cyclic steaming ? horizontal well producer, existing and two new... and contains an OOIP of 7. 037 BSTB. The oil has an oil gravity of 11. 7 degrees API with a viscosity of 635 cp at initial reservoir conditions of 1, 360 psia and 128'F. Currently the reservoir produces 36 MSTB/D oil. Structurally, the reservoir is a simple...

Rodriguez, Manuel Gregorio

2012-06-07T23:59:59.000Z

196

Parametric and predictive analysis of horizontal well configurations for coalbed methane reservoirs in Appalachian Basin.  

E-Print Network (OSTI)

??It has been a well-established fact that the Appalachian Basin represents a high potential region for the Coalbed Methane (CBM) production. The thin coal beds… (more)

Maricic, Nikola.

2004-01-01T23:59:59.000Z

197

Research on Application of Steering Drilling Technologies in Shale Gas Development  

Science Journals Connector (OSTI)

Abstract HF-1 well of Pengye is a sidetracking horizontal well for shale gas development, the directional segment of the well is long, high requirements for well trajectory control of the directional segment in construction process. In allusion to the features and challenges of this well drilling, this paper introduces the application of slide steering drilling system and rotary steerable drilling system in this well, including analyzing all these tool basic principle, the characteristics and field application. The analysis shows that using different angel screw drill tool can meet the needs of increasing hole angle, steadying hole angle and adjusting the orientation; Adoption of EZ-Pilot steerable rotary system solves the problem of remarkable resistance and low degree of hole cleanness in long horizontal section, and satisfies the requirement of drilling and completion of the well. The system also shows the desirable performance in improving ROP and hole quality.

Guang Xinjun; Li Jing

2014-01-01T23:59:59.000Z

198

Bit cutter-on-rock tribometry: Analyzing friction and rate-of-penetration for deep well drilling substrates  

Science Journals Connector (OSTI)

Abstract In this paper, techniques for studying the tribology of rock cutting were developed using bit cutter-on-rock tribometry (B-CORT). Tribological testing was carried out on water-jet fabricated rock disks representative of those found during deep well drilling. The tribometer was also retrofitted with a variable radius cutter assembly, and a system for the capture of in situ rate-of-penetration (ROP). Results include in situ coefficient of friction (COF) and ROP for O1 tool steel cutters on Carthage Marble rock disks. Additionally, this work includes validation of the DOC measurement system with optical interferometry. The interdependence of interfacial cutting friction, ROP, and disk speed are discussed and qualitatively validated against existing studies.

Patrick S.M. Dougherty; Randyka Pudjoprawoto; C. Fred Higgs III

2014-01-01T23:59:59.000Z

199

Analytical study of capture zone of a horizontal well in a confined aquifer  

E-Print Network (OSTI)

to the remediation of contaminated ground water (Langseth, 1990; Tarsh- ish, 1992; Cleveland, 1994; Wilson and Kenda as a part of an aquifer whose ground water will flow to that well. Steward (1999) concluded that Journal a large planar area during remediation, and is more efficient in removing contaminant relative to vertical

Zhan, Hongbin

200

Two-phase pressure transient analysis for multi-stage fractured horizontal well in shale gas reservoirs  

Science Journals Connector (OSTI)

Abstract Most researches on shale gas production and pressure transient analysis placed more emphasis on single-phase flow, the two-phase flow caused by flowback after hydrofracture in shale gas reservoirs does not attract much attention. This paper presents a two-phase pressure transient analysis model of multi-stage fractured horizontal well with the consideration of wellbore storage, skin effect, two-phase saturation, hydraulic fractures parameters and desorption characteristics of shale gas reservoirs. Accurate solution to this flow model is obtained by the use of source function theory, Laplace transform, three-dimensional eigenvalue method and orthogonal transformation. Pseudo-pressure and pseudo-pressure derivative type curve is plotted by using the Stehfest algorithm. Seven different flow regimes have been identified and the effects of influence factors such as initial saturation, skin factor, absorption index, fracture stages, horizontal well lateral length and wellbore storage coefficient have also been discussed. The presents research could be used to interpret the pressure behavior more accurately and effectively of shale gas reservoirs.

Weiyang Xie; Xiaoping Li; Liehui Zhang; Junchao Wang; Lina Cao; Lin Yuan

2014-01-01T23:59:59.000Z

Note: This page contains sample records for the topic "horizontal wells drilling" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


201

Interpretation of Array Production Logging Measurements in Horizontal Wells for Flow Profile  

E-Print Network (OSTI)

. The mean velocity of a phase at the heel location is then j jdh j A qv ,? (2.11) where jA is the area of all segments occupied by phase j . We... that the bottom two segments of the well cross-section are occupied by water. Then, 54 , AA qv wdhw ?? (2.15) And the array spinner response to water at the heel...

Liao, Lulu

2013-12-12T23:59:59.000Z

202

Earth drill rig  

SciTech Connect

This patent describes an earth drill rig wherein an upwardly and downwardly moving drill-string-turning rotary table is rotated by a kelly bar connected at its lower end to a vertical drive shaft, the kelly bar being journalled for rotation in and fixed against axial movement with respect to a drill frame assembly and the rotary table being mounted for axial movement on and along the drill frame assembly. The drill frame assembly is pivotally mounted on a vehicle on a substantially horizontal axis for pivoting between an upright position and a substantially horizontal position for transportation. The improvement described here comprises the drill frame assembly pivot axis positioned below the lower end of the kelly bar and above the upper end of the vertical drive shaft, and a universal coupling connecting the lower end of the kelly bar and the vertical drive shaft the universal coupling comprising universal joints at opposite ends of an elongated slip joint connector and connected there-by for relative axial movement but driving coupling between the universal joints. The universal joints lie generally on a circle of which the drill frame assembly pivot axis is the center. The drill frame assembly can be moved between the upright and the substantially horizontal positions without disconnecting the kelly bar from the vertical drive shaft, the kelly bar being revolvable by the drive shaft through substantially the entire range of movement of the drill frame assembly.

Rassieur, C.L.

1987-01-27T23:59:59.000Z

203

Advanced Reservoir Characterization and Development through High-Resolution 3C3D Seismic and Horizontal Drilling: Eva South Marrow Sand Unit, Texas County, Oklahoma  

SciTech Connect

The Eva South Morrow Sand Unit is located in western Texas County, Oklahoma. The field produces from an upper Morrow sandstone, termed the Eva sandstone, deposited in a transgressive valley-fill sequence. The field is defined as a combination structural stratigraphic trap; the reservoir lies in a convex up -dip bend in the valley and is truncated on the west side by the Teepee Creek fault. Although the field has been a successful waterflood since 1993, reservoir heterogeneity and compartmentalization has impeded overall sweep efficiency. A 4.25 square mile high-resolution, three component three-dimensional (3C3D) seismic survey was acquired in order to improve reservoir characterization and pinpoint the optimal location of a new horizontal producing well, the ESU 13-H.

Wheeler,David M.; Miller, William A.; Wilson, Travis C.

2002-03-11T23:59:59.000Z

204

Environmental Assessment: Geothermal Energy Geopressure Subprogram. Gulf Coast Well Drilling and Testing Activity (Frio, Wilcox, and Tuscaloosa Formations, Texas and Louisiana)  

SciTech Connect

The Department of Energy (DOE) has initiated a program to evaluate the feasibility of developing the geothermal-geopressured energy resources of the Louisiana-Texas Gulf Coast. As part of this effort, DOE is contracting for the drilling of design wells to define the nature and extent of the geopressure resource. At each of several sites, one deep well (4000-6400 m) will be drilled and flow tested. One or more shallow wells will also be drilled to dispose of geopressured brines. Each site will require about 2 ha (5 acres) of land. Construction and initial flow testing will take approximately one year. If initial flow testing is successful, a continuous one-year duration flow test will take place at a rate of up to 6400 m{sup 3} (40,000 bbl) per day. Extensive tests will be conducted on the physical and chemical composition of the fluids, on their temperature and flow rate, on fluid disposal techniques, and on the reliability and performance of equipment. Each project will require a maximum of three years to complete drilling, testing, and site restoration.

None

1981-09-01T23:59:59.000Z

205

Department of Mechanical Engineering Spring 2010 Kenya Water Well Drill Rig Redesign of Engine Drive Train System & Support Tower  

E-Print Network (OSTI)

of Engine Drive Train System & Support Tower Overview The team was presented with the task of redesigning the engine drive train system and support structure for a water drill rig to be used in Kenya. The original engine drive train system was fabricated by a professional machinist and had many intricate components

Demirel, Melik C.

206

Influence of the Drilling Mud Formulation Process on the Bacterial Communities in Thermogenic Natural Gas Wells of the Barnett Shale  

Science Journals Connector (OSTI)

...number of problems that lead to significant costs for the oil and natural gas industries...acceptor and as a source of carbon and energy for microbial populations in drilling...Polyphasic analysis of Thermus isolates from geothermal areas in Iceland. Extremophiles 10...

Christopher G. Struchtemeyer; James P. Davis; Mostafa S. Elshahed

2011-05-20T23:59:59.000Z

207

Technology summary of the in situ bioremediation demonstration (methane biostimulation) via horizontal wells at the Savannah River Site Integrated Demonstration Project  

SciTech Connect

The US Department of Energy, Office of Technology Development, has been sponsoring full-scale environmental restoration technology demonstrations for the past 4 years. The Savannah River Site Integrated Demonstration focuses on ``Clean-up of Soils ad Groundwater Contaminated with Chlorinated VOCs.`` Several laboratories including our own had demonstrated the ability of methanotrophic bacteria to completely degrade or mineralize chlorinated solvents, and these bacteria were naturally found in soil and aquifer material. Thus the test consisted of injection of methane mixed with air into the contaminated aquifer via a horizontal well and extraction from the vadose zone via a parallel horizontal well.

Hazen, T.C.; Looney, B.B.; Fliermans, C.B.; Eddy-Dilek, C.A. [Westinghouse Savannah River Co., Aiken, SC (United States); Lombard, K.H. [Bechtel Savannah River, Inc., Aiken, SC (United States); Enzien, M.V. [Argonne National Lab., IL (United States); Dougherty, J.M. [US Environmental Protection Agency, Irving, TX (United States); Wear, J. [Catawba State Coll., Salisbury, NC (United States)

1994-06-01T23:59:59.000Z

208

The Implications and Flow Behavior of the Hydraulically Fractured Wells in Shale Gas Formation  

E-Print Network (OSTI)

approaches is by drilling horizontal wells and hydraulically fracturing the formation. Once the formation is fractured, different flow patterns will occur. The dominant flow regime observed in the shale gas formation is the linear flow or the transient...

Almarzooq, Anas Mohammadali S.

2012-02-14T23:59:59.000Z

209

Recovery Efficiency Test Project: Phase 1, Activity report. Volume 1: Site selection, drill plan preparation, drilling, logging, and coring operations  

SciTech Connect

The recovery Efficiency Test well project addressed a number of technical issues. The primary objective was to determine the increased efficiency gas recovery of a long horizontal wellbore over that of a vertical wellbore and, more specifically, what improvements can be expected from inducing multiple hydraulic fractures from such a wellbore. BDM corporation located, planned, and drilled a long radius turn horizontal well in the Devonian shale Lower Huron section in Wayne County, West Virginia, demonstrating that state-of-the-art technology is capable of drilling such wells. BDM successfully tested drilling, coring, and logging in a horizontal well using air as the circulating medium; conducted reservoir modeling studies to protect flow rates and reserves in advance of drilling operations; observed two phase flow conditions in the wellbore not observed previously; cored a fracture zone which produced gas; observed that fractures in the core and the wellbore were not systematically spaced (varied from 5 to 68 feet in different parts of the wellbore); observed that highest gas show rates reported by the mud logger corresponded to zone with lowest fracture spacing (five feet) or high fracture frequency. Four and one-half inch casting was successfully installed in the borehole and was equipped to isolate the horizontal section into eight (8) zones for future testing and stimulation operations. 6 refs., 48 figs., 10 tabs.

Overbey, W.K. Jr.; Carden, R.S.; Kirr, J.N.

1987-04-01T23:59:59.000Z

210

Sweet lake geopressured-geothermal project, Magma Gulf-Technadril/DOE Amoco Fee. Annual report, December 1, 1979-February 27, 1981. Volume I. Drilling and completion test well and disposal well  

SciTech Connect

The Sweet lake site is located approximately 15 miles southeast of Lake Charles in Cameron Parish, Louisiana. A geological study showed that the major structure in this area is a graben. The dip of the beds is northwesterly into the basin. A well drilled into the deep basin would find the target sand below 18,000', at high pressures and temperatures. However, since there is no well control in the basin, the specific site was chosen on the 15,000' contour of the target sand in the eastern, more narrow part of the garben. Those key control wells are present within one mile of the test well. The information acquired by drilling the test well confirmed the earlier geologic study. The target sand was reached at 15,065', had a porosity of over 20% and a permeability to water of 300 md. The original reservoir pressure was 12,060 psi and the bottom hole temperature 299{sup 0}F. There are approximately 250 net feet of sand available for the perforation. The disposal well was drilled to a total depth of 7440'.

Rodgers, R.W. (ed.)

1982-06-01T23:59:59.000Z

211

Drilling Waste Management Fact Sheet: Drilling Practices That Minimize  

NLE Websites -- All DOE Office Websites (Extended Search)

Drilling Practices Drilling Practices Fact Sheet - Drilling Practices That Minimize Generation of Drilling Wastes How Are Wells Typically Drilled? The conventional process of drilling oil and gas wells uses a rotary drill bit that is lubricated by drilling fluids or muds. As the drill bit grinds downward through the rock layers, it generates large amounts of ground-up rock known as drill cuttings. This section of the Drilling Waste Management Information System website discusses several alternative drilling practices that result in a lower volume of waste being generated. Oil and gas wells are constructed with multiple layers of pipe known as casing. Traditional wells are not drilled from top to bottom at the same diameter but rather in a series of progressively smaller-diameter intervals. The top interval is drilled starting at the surface and has the largest diameter hole. Drill bits are available in many sizes to drill different diameter holes. The hole diameter can be 20" or larger for the uppermost sections of the well, followed by different combinations of progressively smaller diameters. Some of the common hole diameters are: 17.5", 14.75", 12.25", 8.5", 7.875", and 6.5".

212

NETL: News Release - Carbon Fiber Drill Pipe Performs Flawlessly in First  

NLE Websites -- All DOE Office Websites (Extended Search)

January 9, 2003 January 9, 2003 Carbon Fiber Drill Pipe Performs Flawlessly in First Field Test Private Company to Use DOE-Sponsored Technology To Help Restore Domestic Production from Older Oil Wells TULSA COUNTY, OK - A new lightweight, flexible drill pipe engineered from space-age composites rather than steel has passed an important field test in a U.S. Department of Energy project and is now being readied for its first commercial use. - Photo - Composite Drill Pipe Being Bent - The advanced composite drill pipe could enable drillers in the future to bore sharply-curved "short radius" horizontal wells without creating fatigue stress on the drill pipe. The Energy Department's National Energy Technology Laboratory announced that the drill pipe, made from carbon fiber resins by Advanced Composite

213

Drilling and production technology symposium  

SciTech Connect

This book presents the papers given at a conference on well drilling. Topics considered at the conference included ice island drilling structures, artificial intelligence, electric motors, mud pumps, bottom hole assembly failures, oil spills, corrosion, wear characteristics of drill bits, two-phase flow in marine risers, the training of drilling personnel, and MWD systems.

Welch, R.

1986-01-01T23:59:59.000Z

214

HydroPulse Drilling  

SciTech Connect

Tempress HydroPulse{trademark} tool increases overbalanced drilling rates by generating intense suction pulses at the drill bit. This report describes the operation of the tool; results of pressure drilling tests, wear tests and downhole drilling tests; and the business case for field applications. The HydroPulse{trademark} tool is designed to operate on weighted drilling mud at conventional flow rates and pressures. Pressure drilling tests confirm that the HydroPulse{trademark} tool provides 33% to 200% increased rate of penetration. Field tests demonstrated conventional rotary and mud motor drilling operations. The tool has been operated continuous for 50 hours on weighted mud in a wear test stand. This level of reliability is the threshold for commercial application. A seismic-while-drilling version of the tool was also developed and tested. This tool was used to demonstrate reverse vertical seismic profiling while drilling an inclined test well with a PDC bit. The primary applications for the HydroPulse{trademark} tool are deep onshore and offshore drilling where rate of penetration drives costs. The application of the seismic tool is vertical seismic profiling-while-drilling and look-ahead seismic imaging while drilling.

J.J. Kolle

2004-04-01T23:59:59.000Z

215

Managed pressure drilling techniques and tools  

E-Print Network (OSTI)

these problems, the economics of drilling the wells will improve, thus enabling the industry to drill wells that were previously uneconomical. Managed pressure drilling (MPD) is a new technology that enables a driller to more precisely control annular pressures...

Martin, Matthew Daniel

2006-08-16T23:59:59.000Z

216

300-Area VOC Program Slug Test Characterization Results for Selected Test/Depth Intervals Conducted During the Drilling of Well 399-3-21  

SciTech Connect

This report presents brief test descriptions and analysis results for multiple, stress-level slug tests that were performed at selected test/depth intervals within well 399-3-21 as part of the 300-Area volatile organic compound characterization program. The test intervals were characterized as the borehole was advanced to its final drill depth (45.7 m) and before its completion as a monitor-well facility. The primary objective of the slug tests was to provide information pertaining to the vertical distribution of hydraulic conductivity with depth at this location and to select the final screen-depth interval for the monitor well. This type of characterization information is important for predicting/simulating contaminant migration (i.e., numerical flow/transport modeling) and designing proper monitor-well strategies within this area.

Spane, Frank A.

2007-07-19T23:59:59.000Z

217

Design and Implementation of a CO2 Flood Utilizing Advanced Reservoir Characterization and Horizontal Injection Wells In a Shallow Shelf Carbonate Approaching Waterflood Depletion, Class II  

SciTech Connect

The purpose of this project was to economically design an optimum carbon dioxide (CO2) flood for a mature waterflood nearing its economic abandonment. The original project utilized advanced reservoir characterization and CO2 horizontal injection wells as the primary methods to redevelop the South Cowden Unit (SCU). The development plans; project implementation and reservoir management techniques were to be transferred to the public domain to assist in preventing premature abandonment of similar fields.

Wier, Don R. Chimanhusky, John S.; Czirr, Kirk L.; Hallenbeck, Larry; Gerard, Matthew G.; Dollens, Kim B.; Owen, Rex; Gaddis, Maurice; Moshell, M.K.

2002-11-18T23:59:59.000Z

218

Managed Pressure Drilling Candidate Selection  

E-Print Network (OSTI)

. Rodolphe Leschot invented and patented the earliest form of diamond core drills. T. F. Rowland patented an ?offshore rotary drilling rig?. Captain Lucas, with his Spindletop field wells, Earle Halliburton with his cementing service company, inventors... is the ancient water and brine wells drilled from the prehistoric eras to not so modern times. The second stage is the drilling of the earliest oil wells, and development of basic derricks, rigs, and cable tool rigs. The third stage is the development of rotary...

Nauduri, Anantha S.

2010-07-14T23:59:59.000Z

219

Well control procedures for extended reach wells  

E-Print Network (OSTI)

been found to be critical to the success of ERD are torque and drag, drillstring design, wellbore stability, hole cleaning, casing design, directional drilling optimization, drilling dynamics and rig sizing.4 Other technologies of vital importance... are the use of rotary steerable systems (RSS) together with measurement while drilling (MWD) and logging while drilling (LWD) to geosteer the well into the geological target.5 Many of the wells drilled at Wytch Farm would not have been possible to drill...

Gjorv, Bjorn

2004-09-30T23:59:59.000Z

220

oil-base(d) (rotary) drilling fluid  

Science Journals Connector (OSTI)

oil-base(d) (rotary) drilling fluid, oil-base(d) fluid [Used primarily for drilling-in or recomputing wells in formations subject ... with low formation pressures. See remark under “drilling fluid”] ...

2014-08-01T23:59:59.000Z

Note: This page contains sample records for the topic "horizontal wells drilling" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


221

Microhole Drilling Tractor Technology Development  

SciTech Connect

In an effort to increase the U.S. energy reserves and lower costs for finding and retrieving oil, the USDOE created a solicitation to encourage industry to focus on means to operate in small diameter well-Microhole. Partially in response to this solicitation and because Western Well Tool's (WWT) corporate objective to develop small diameter coiled tubing drilling tractor, WWT responded to and was awarded a contract to design, prototype, shop test, and field demonstrate a Microhole Drilling Tractor (MDT). The benefit to the oil industry and the US consumer from the project is that with the MDT's ability to facilitate Coiled Tubing drilled wells to be 1000-3000 feet longer horizontally, US brown fields can be more efficiently exploited resulting in fewer wells, less environmental impact, greater and faster oil recovery, and lower drilling costs. Shortly after award of the contract, WWT was approached by a major oil company that strongly indicated that the specified size of a tractor of 3.0 inches diameter was inappropriate and that immediate applications for a 3.38-inch diameter tractor would substantially increase the usefulness of the tool to the oil industry. Based on this along with an understanding with the oil company to use the tractor in multiple field applications, WWT applied for and was granted a no-cost change-of-scope contract amendment to design, manufacture, assemble, shop test and field demonstrate a prototype a 3.38 inch diameter MDT. Utilizing existing WWT tractor technology and conforming to an industry developed specification for the tool, the Microhole Drilling Tractor was designed. Specific features of the MDT that increase it usefulness are: (1) Operation on differential pressure of the drilling fluid, (2) On-Off Capability, (3) Patented unique gripping elements (4) High strength and flexibility, (5) Compatibility to existing Coiled Tubing drilling equipment and operations. The ability to power the MDT with drilling fluid results in a highly efficient tool that both delivers high level of force for the pressure available and inherently increases downhole reliability because parts are less subject to contamination. The On-Off feature is essential to drilling to allow the Driller to turn off the tractor and pull back while circulating in cleanout runs that keep the hole clean of drilling debris. The gripping elements have wide contact surfaces to the formation to allow high loads without damage to the formation. As part of the development materials evaluations were conducted to verify compatibility with anticipated drilling and well bore fluids. Experiments demonstrated that the materials of the tractor are essentially undamaged by exposure to typical drilling fluids used for horizontal coiled tubing drilling. The design for the MDT was completed, qualified vendors identified, parts procured, received, inspected, and a prototype was assembled. As part of the assembly process, WWT prepared Manufacturing instructions (MI) that detail the assembly process and identify quality assurance inspection points. Subsequent to assembly, functional tests were performed. Functional tests consisted of placing the MDT on jack stands, connecting a high pressure source to the tractor, and verifying On-Off functions, walking motion, and operation over a range of pressures. Next, the Shop Demonstration Test was performed. An existing WWT test fixture was modified to accommodate operation of the 3.38 inch diameter MDT. The fixture simulated the tension applied to a tractor while walking (pulling) inside 4.0 inch diameter pipe. The MDT demonstrated: (1) On-off function, (2) Pulling forces proportional to available differential pressure up to 4000 lbs, (3) Walking speeds to 1100 ft/hour. A field Demonstration of the MDT was arranged with a major oil company operating in Alaska. A demonstration well with a Measured Depth of approximately 15,000 ft was selected; however because of problems with the well drilling was stopped before the planned MDT usage. Alternatively, functional and operational tests were run with the MDT insi

Western Well Tool

2007-07-09T23:59:59.000Z

222

Chapter 4 Drilling Engineering  

Science Journals Connector (OSTI)

Publisher Summary Drilling operations are essentially carried out during all stages of the project life cycle (PLC) and in all types of environments. The main objectives of these operations includes: the acquisition of information and the safeguarding of production. Since the expenditure for drilling represents a large fraction of the total project's capital expenditure, an understanding of the techniques, equipment, and cost of drilling is very significant. This chapter focuses on the drilling activities. The chapter also explores the interactions between the drilling team and the other exploration and production (E&P) functions. Specifically, an initial successful exploration well can establish the presence of a working petroleum system. Following this, the data gathered in the first well is evaluated and the results are documented. The next step includes the appraisal of the accumulation requiring more wells. Finally, if the project is subsequently moved forward, development wells then needs to be engineered.

F. Jahn; M. Cook; M. Grahm

2008-01-01T23:59:59.000Z

223

Lateral Drilling and Completion Technologies for Shallow-Shelf Carbonates of the Red River and Ratcliffe Formations, Williston Basin  

SciTech Connect

Luff Exploration Company (LEC) focused on involvement in technologies being developed utilizing horizontal drilling concepts to enhance oil- well productivity starting in 1992. Initial efforts were directed toward high-pressure lateral jetting techniques to be applied in existing vertical wells. After involvement in several failed field attempts with jetting technologies, emphasis shifted to application of emerging technologies for drilling short-radius laterals in existing wellbores and medium-radius technologies in new wells. These lateral drilling technologies were applied in the Mississippi Ratcliffe and Ordovician Red River formations at depths of 2590 to 2890 m (8500 to 9500 ft) in Richland Co., MT; Bowman Co., ND; and Harding Co., SD.

David Gibbons; Larry A. Carrell; Richard D. George

1997-07-31T23:59:59.000Z

224

DRILL-STRING NONLINEAR DYNAMICS ACCOUNTING FOR DRILLING FLUID T. G. Ritto  

E-Print Network (OSTI)

;1. INTRODUCTION A drill-string is a slender structure used in oil wells to penetrate the soil in search of oilDRILL-STRING NONLINEAR DYNAMICS ACCOUNTING FOR DRILLING FLUID T. G. Ritto R. Sampaio thiagoritto Descartes, 77454 Marne-la-Vallée, France Abstract. The influence of the drilling fluid (or mud) on the drill

Boyer, Edmond

225

Advanced Mud System for Microhole Coiled Tubing Drilling  

SciTech Connect

An advanced mud system was designed and key components were built that augment a coiled tubing drilling (CTD) rig that is designed specifically to drill microholes (less than 4-inch diameter) with advanced drilling techniques. The mud system was tailored to the hydraulics of the hole geometries and rig characteristics required for microholes and is capable of mixing and circulating mud and removing solids while being self contained and having zero discharge capability. Key components of this system are two modified triplex mud pumps (High Pressure Slurry Pumps) for advanced Abrasive Slurry Jetting (ASJ) and a modified Gas-Liquid-Solid (GLS) Separator for well control, flow return and initial processing. The system developed also includes an additional component of an advanced version of ASJ which allows cutting through most all materials encountered in oil and gas wells including steel, cement, and all rock types. It includes new fluids and new ASJ nozzles. The jetting mechanism does not require rotation of the bottom hole assembly or drill string, which is essential for use with Coiled Tubing (CT). It also has low reactive forces acting on the CT and generates cuttings small enough to be easily cleaned from the well bore, which is important in horizontal drilling. These cutting and mud processing components and capabilities compliment the concepts put forth by DOE for microhole coiled tubing drilling (MHTCTD) and should help insure the reality of drilling small diameter holes quickly and inexpensively with a minimal environmental footprint and that is efficient, compact and portable. Other components (site liners, sump and transfer pumps, stacked shakers, filter membranes, etc.. ) of the overall mud system were identified as readily available in industry and will not be purchased until we are ready to drill a specific well.

Kenneth Oglesby

2008-12-01T23:59:59.000Z

226

Advanced drilling systems study.  

SciTech Connect

This report documents the results of a study of advanced drilling concepts conducted jointly for the Natural Gas Technology Branch and the Geothermal Division of the U.S. Department of Energy. A number of alternative rock cutting concepts and drilling systems are examined. The systems cover the range from current technology, through ongoing efforts in drilling research, to highly speculative concepts. Cutting mechanisms that induce stress mechanically, hydraulically, and thermally are included. All functions necessary to drill and case a well are considered. Capital and operating costs are estimated and performance requirements, based on comparisons of the costs for alternative systems to conventional drilling technology, are developed. A number of problems common to several alternatives and to current technology are identified and discussed.

Pierce, Kenneth G.; Livesay, Billy Joe; Finger, John Travis (Livesay Consultants, Encintas, CA)

1996-05-01T23:59:59.000Z

227

Drilling operations change gear  

SciTech Connect

Predicts that several technological developments (e.g. measurement-while-drilling tools, computer data-gathering systems, improved drill bits, muds, downhole mud motors, and more efficient rigs) will have a major effect on drilling operations in the not-too-distant future. While several companies manufacture MWD systems and most can boast of successful runs, the major problem with the MWD system is cost. Manufacturers continue to make advances in both turbine and positive displacement mud motors. As the life span of downhole mud motors improves, these motors can economically compete with a rotary rig in drilling certain straight-hole intervals. Prototype bit designs include the use of lasers, electronic beams, flames, sparks, explosives, rocket exhaust, chains, projectiles, abrasive jets, and high-pressure erosion. Because drilling fluids are taking a large share of the drilling budget, mud engineers are trying to optimize costs, while maintaining well bore stability and increasing penetration rates. Many companies are taking the strategy of designing the simplest mud program possible and increasing additives only as needed. Air and foam drilling techniques are gaining attention. Concludes that as crude oil prices increase and the rig count begins to rebound, attention will once again turn to drilling technology and methodology.

Moore, S.D.

1982-08-01T23:59:59.000Z

228

Slug Test Characterization Results for Multi-Test/Depth Intervals Conducted During the Drilling of CERCLA Operable Unit OU ZP-1 Wells 299-W10-33 and 299-W11-48  

SciTech Connect

Slug-test results obtained from single and multiple, stress-level slug tests conducted during drilling and borehole advancement provide detailed hydraulic conductivity information at two Hanford Site Operable Unit (OU) ZP-1 test well locations. The individual test/depth intervals were generally sited to provide hydraulic-property information within the upper ~10 m of the unconfined aquifer (i.e., Ringold Formation, Unit 5). These characterization results complement previous and ongoing drill-and-test characterization programs at surrounding 200-West and -East Area locations (see Figure S.1).

Newcomer, Darrell R.

2007-09-30T23:59:59.000Z

229

Drilling optimization using drilling simulator software  

E-Print Network (OSTI)

equipment is being used on some rigs, adding more overall costs to the drilling operation. Other industries facing a similar dilemma-aerospace, airlines, utilities, and the military- have all resorted to sophisticated training and technology... and Gaebler3). Rotary Speed, RPM Weight on Bit, Klbs Rotary Speed, RPM Weight on Bit, Klbs Rotary Speed, RPM Weight on Bit, Klbs ROP,m/h 10 20 7 Fig. 3 shows the five basic processes encountered during the drilling of a well that account for more...

Salas Safe, Jose Gregorio

2004-09-30T23:59:59.000Z

230

Design and Analysis of a Test Rig for Modeling the Bit/Formation Interface in Petroleum Drilling Applications  

E-Print Network (OSTI)

and horizontal wells and measuring the effects of various factors on the stability of perturbations on the system. A test rig concept has been developed to accurately measure the interaction forces and torques between the bit, formation and fluids during drilling...

Wilson, Joshua Kyle

2013-04-11T23:59:59.000Z

231

Drill bit having a failure indicator  

SciTech Connect

A lubrication system is described to indicate a decrease in lubricant volume below a predetermined level in a rotary drill bit having a bit body adapted to receive drilling fluid at a high first pressure from a suspended drill string, and adapted to discharge the drilling fluid therefrom in a void space between the bit body and an associated well bore with the drilling fluid in the space being at a low second pressure.

Daly, J.E.; Pastusek, P.E.

1986-09-09T23:59:59.000Z

232

Summary report of the drilling technologies tested at the Integrated Demonstration Project for cleanup of organic contaminants in soils and groundwater at non-arid sites  

SciTech Connect

The Department of Energy`s Office of Technology Development initiated an integrated demonstration of innovative technologies and systems for cleanup of volatile organic compounds in soil and groundwater at SRS. The overall goal of the program is the demonstration of multiple technologies and systems in the fields of drilling, characterization, monitoring, and remediation at a single test bed. Horizontal environmental well installation technology was one of the remediation technologies that was demonstrated at SRS. Four distinctly different systems of directional drilling and horizontal well installations were successfully demonstrated and evaluated. The four systems were developed in the petroleum industry, the river crossing industry, and the utility industry. The transfer of information concerning the horizontal environmental well installations has been facilitated by publishing a series of reports describing each individual demonstration. This is the final report in the series and provides a comprehensive evaluation of all four systems. The objectives of this report are to summarize the strengths and weaknesses of each drilling technology, describe and compare the problems encountered by each drilling technology, compare the compatibility of each technology with varying logistical and geological conditions, and discuss the expense of using each technology. This report is designed to be a horizontal environmental well reference document for the environmental remediation industry. An environmental problem holder may use this report to evaluate a directional drilling technology for use at his/her site.

Not Available

1993-11-01T23:59:59.000Z

233

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

SciTech Connect

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.

Joe Sinner

2002-01-16T23:59:59.000Z

234

A real-time borehole correction of electromagnetic wave resistivity logging while drilling  

Science Journals Connector (OSTI)

Abstract The response of electromagnetic wave logging while drilling is influenced greatly by borehole and drilling fluid resistivity when the size of borehole is relatively large and drilling fluid resistivity is low. Borehole radius and drilling fluid resistivity were introduced to obtain more accurate transformed resistivity on the basis of the commonly used resistivity transformation model. The influence of borehole was considered in the newly established three dimensional transformation model, and a new borehole correction method was proposed. The resistivity transformation database can be established by calculation according to a certain instrument, and the true resistivity is obtained by three dimensional interpolation search technology of real-time correction in practical use. The results of numerical simulation and modeling verification show that the transformed resistivity by real-time correction coincides with the resistivity corrected by charts. The method can eliminate the borehole influence, reduce calculation dimension, and improve the inversion efficiency of highly deviated and horizontal wells logging data.

Zhen YANG; Jinzhou YANG; Laiju HAN

2013-01-01T23:59:59.000Z

235

Noble gases identify the mechanisms of fugitive gas contamination in drinking-water wells overlying the  

E-Print Network (OSTI)

12, 2014 (received for review November 27, 2013) Horizontal drilling and hydraulic fracturing have triggered by horizontal drilling or hydraulic fracturing. noble gas geochemistry | groundwater contamination and hydraulic fracturing have substantially increased hydrocarbon recovery from black shales and other

Jackson, Robert B.

236

Integrated approach towards the application of horizontal wells to improve waterflooding performance. Annual progress report, January 1, 1996--December 31, 1996  

SciTech Connect

This annual report describes the progress during the fourth year of the project on {open_quotes}Integrated Approach Towards the Application of Horizontal Wells to Improve Waterflooding Performance{close_quotes}. The project involves using an integrated approach to characterize the reservoir followed by proposing an appropriate reservoir management strategy to improve the field performance. In the first stage of the project, the type of data we integrated include cross borehole seismic surveys, geological interpretation based on the logs and the cores, and the engineering information. In contrast, during the second stage of the project, we intend to use only conventional data to construct the reservoir description. This report covers the results of the implementation from the first stage of the project. It also discusses the work accomplished so far for the second stage of the project. The production from the Self Unit (location of Stage 1) has sustained an increase of 30 bbls/day over a year with an additional increase anticipated with further implementation. We have collected available core, log and production data from Section 16 in the Berryhill Glenn Unit and have finished the geological description. Based on the geological description and the associated petrophysical properties, we have developed a new indexing procedure for identifying the areas with the most potential. We are also investigating an adjoining tract formerly operated by Chevron where successful miceller-polymer flood was conducted. This will help us in evaluating the reasons for the success of the flood. Armed with this information, we will conduct a detailed geostatistical and flow simulation study and recommend the best reservoir management plan to improve the recovery of the field.

Kelkar, M.; Liner, C.; Kerr, D.

1997-01-01T23:59:59.000Z

237

Near-Term Developments in Geothermal Drilling  

SciTech Connect

The DOE Hard Rock Penetration program is developing technology to reduce the costs of drilling geothermal wells. Current projects include: R & D in lost circulation control, high temperature instrumentation, underground imaging with a borehole radar insulated drill pipe development for high temperature formations, and new technology for data transmission through drill pipe that can potentially greatly improve data rates for measurement while drilling systems. In addition to this work, projects of the Geothermal Drilling Organization are managed. During 1988, GDO projects include developments in five areas: high temperature acoustic televiewer, pneumatic turbine, urethane foam for lost circulation control, geothermal drill pipe protectors, an improved rotary head seals.

Dunn, James C.

1989-03-21T23:59:59.000Z

238

Directional drilling techniques for exploration in-advance of mining  

SciTech Connect

In-seam directionally drilled horizontal boreholes have provided effective solutions in underground coal mines for methane and water drainage and inherently provide an excellent tool for coalbed exploration. Directionally drilled methane drainage boreholes have identified rapid changes in coalbed elevation, coalbed thickness and faults. Specific directional drilling and coring procedures for exploration in-advance of mining are reviewed in this paper, and also other directional drilling applications including in-mine horizontal gob ventilation boreholes, identification of abandoned workings, and water drainage boreholes.

Kravits, S.J.; Schwoebel, J.J. (REI Underground Exploration Inc., Salt Lake City, UT (United States))

1994-01-01T23:59:59.000Z

239

DEVELOPMENT OF NEW DRILLING FLUIDS  

SciTech Connect

The goal of the project has been to develop new types of drill-in fluids (DIFs) and completion fluids (CFs) for use in natural gas reservoirs. Phase 1 of the project was a 24-month study to develop the concept of advanced type of fluids usable in well completions. Phase 1 tested this concept and created a kinetic mathematical model to accurately track the fluid's behavior under downhole conditions. Phase 2 includes tests of the new materials and practices. Work includes the preparation of new materials and the deployment of the new fluids and new practices to the field. The project addresses the special problem of formation damage issues related to the use of CFs and DIFs in open hole horizontal well completions. The concept of a ''removable filtercake'' has, as its basis, a mechanism to initiate or trigger the removal process. Our approach to developing such a mechanism is to identify the components of the filtercake and measure the change in the characteristics of these components when certain cleanup (filtercake removal) techniques are employed.

David B. Burnett

2003-08-01T23:59:59.000Z

240

HYDRATE CORE DRILLING TESTS  

SciTech Connect

The ''Methane Hydrate Production from Alaskan Permafrost'' project is a three-year endeavor being conducted by Maurer Technology Inc. (MTI), Noble, and Anadarko Petroleum, in partnership with the U.S. DOE National Energy Technology Laboratory (NETL). The project's goal is to build on previous and ongoing R&D in the area of onshore hydrate deposition. The project team plans to design and implement a program to safely and economically drill, core and produce gas from arctic hydrates. The current work scope includes drilling and coring one well on Anadarko leases in FY 2003 during the winter drilling season. A specially built on-site core analysis laboratory will be used to determine some of the physical characteristics of the hydrates and surrounding rock. Prior to going to the field, the project team designed and conducted a controlled series of coring tests for simulating coring of hydrate formations. A variety of equipment and procedures were tested and modified to develop a practical solution for this special application. This Topical Report summarizes these coring tests. A special facility was designed and installed at MTI's Drilling Research Center (DRC) in Houston and used to conduct coring tests. Equipment and procedures were tested by cutting cores from frozen mixtures of sand and water supported by casing and designed to simulate hydrate formations. Tests were conducted with chilled drilling fluids. Tests showed that frozen core can be washed out and reduced in size by the action of the drilling fluid. Washing of the core by the drilling fluid caused a reduction in core diameter, making core recovery very difficult (if not impossible). One successful solution was to drill the last 6 inches of core dry (without fluid circulation). These tests demonstrated that it will be difficult to capture core when drilling in permafrost or hydrates without implementing certain safeguards. Among the coring tests was a simulated hydrate formation comprised of coarse, large-grain sand in ice. Results with this core showed that the viscosity of the drilling fluid must also be carefully controlled. When coarse sand was being cored, the core barrel became stuck because the drilling fluid was not viscous enough to completely remove the large grains of sand. These tests were very valuable to the project by showing the difficulties in coring permafrost or hydrates in a laboratory environment (as opposed to a field environment where drilling costs are much higher and the potential loss of equipment greater). Among the conclusions reached from these simulated hydrate coring tests are the following: Frozen hydrate core samples can be recovered successfully; A spring-finger core catcher works best for catching hydrate cores; Drilling fluid can erode the core and reduces its diameter, making it more difficult to capture the core; Mud must be designed with proper viscosity to lift larger cuttings; and The bottom 6 inches of core may need to be drilled dry to capture the core successfully.

John H. Cohen; Thomas E. Williams; Ali G. Kadaster; Bill V. Liddell

2002-11-01T23:59:59.000Z

Note: This page contains sample records for the topic "horizontal wells drilling" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


241

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

SciTech Connect

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.

Joe Sinner

2001-08-10T23:59:59.000Z

242

Proposed Drill Sites  

SciTech Connect

Proposed drill sites for intermediate depth temperature gradient holes and/or deep resource confirmation wells. Temperature gradient contours based on shallow TG program and faults interpreted from seismic reflection survey are shown, as are two faults interpreted by seismic contractor Optim but not by Oski Energy, LLC.

Lane, Michael

2013-06-28T23:59:59.000Z

243

Proposed Drill Sites  

DOE Data Explorer (OSTI)

Proposed drill sites for intermediate depth temperature gradient holes and/or deep resource confirmation wells. Temperature gradient contours based on shallow TG program and faults interpreted from seismic reflection survey are shown, as are two faults interpreted by seismic contractor Optim but not by Oski Energy, LLC.

Lane, Michael

244

Definition: Drilling Techniques | Open Energy Information  

Open Energy Info (EERE)

Techniques Techniques Jump to: navigation, search Dictionary.png Drilling Techniques There are a variety of drilling techniques which can be used to sink a borehole into the ground. Each has its advantages and disadvantages, in terms of the depth to which it can drill, the type of sample returned, the costs involved and penetration rates achieved. There are two basic types of drills: drills which produce rock chips, and drills which produce core samples.[1] View on Wikipedia Wikipedia Definition Well drilling is the process of drilling a hole in the ground for the extraction of a natural resource such as ground water, brine, natural gas, or petroleum, for the injection of a fluid from surface to a subsurface reservoir or for subsurface formations evaluation or monitoring.

245

New multilateral well architecture in heterogeneous reservoirs  

E-Print Network (OSTI)

the drilling of the main horizontal well and it is cemented together with the main horizontal section. The pressure and structural integrity of these junctions is critical requirement. This integrity does not have to be compromised by any additional... with 15 horizontal lateral model Case 1 Case 6 CMG Results Eclipse Results CMG Results K v/Kh J STBD/psi J STBD/psi J(Case6)/J(Case 1) J STBD/psi J(Case6)/J(Case1) 1 13.85 12.95 93.5% 13.06 94% 0.1 5.73 5.14 89.7% 5.37 93.7% 0.01 1.93 1...

Jia, Hongqiao

2004-09-30T23:59:59.000Z

246

Forecast of geothermal drilling activity  

SciTech Connect

The numbers of each type of geothermal well expected to be drilled in the United States for each 5-year period to 2000 AD are specified. Forecasts of the growth of geothermally supplied electric power and direct heat uses are presented. The different types of geothermal wells needed to support the forecasted capacity are quantified, including differentiation of the number of wells to be drilled at each major geothermal resource for electric power production. The rate of growth of electric capacity at geothermal resource areas is expected to be 15 to 25% per year (after an initial critical size is reached) until natural or economic limits are approached. Five resource areas in the United States should grow to significant capacity by the end of the century (The Geysers; Imperial Valley; Valles Caldera, NM; Roosevelt Hot Springs, UT; and northern Nevada). About 3800 geothermal wells are expected to be drilled in support of all electric power projects in the United States between 1981 and 2000 AD. Half of the wells are expected to be drilled in the Imperial Valley. The Geysers area is expected to retain most of the drilling activity for the next 5 years. By the 1990's, the Imperial Valley is expected to contain most of the drilling activity.

Brown, G.L.; Mansure, A.J.

1981-10-01T23:59:59.000Z

247

drilling-tools | netl.doe.gov  

NLE Websites -- All DOE Office Websites (Extended Search)

drilling-tools Publications KMD Contacts Project Summaries EPAct 2005 Arctic Energy Office Announcements Software Stripper Wells Tally II: Pipe Tally Sheet for Pocket PC allows...

248

Recovery of bypassed oil in the Dundee Formation using horizontal drains. Annual report, March 1996--March 1997  

SciTech Connect

This Class II field project has demonstrated that economic quantities of hydrocarbons can be produced from abandoned or nearly abandoned fields in the Dundee Formation of Central Michigan using horizontal drilling technology. The site selected for the demonstration horizontal well was Crystal Field, a nearly abandoned Dundee oil field in Montcalm County, Michigan. This field had produced over 8 million barrels of oil, mostly in the 1930`s and 1940`s. At the height of development, Crystal Field produced from 193 wells, but by 1995, only seven producing wells remained, each producing less than 10 bbls/day. A horizontal well, the TOW 1-3, drilled as a field demonstration pilot was successful, producing at rate of 100 bbls of oil per day with a zero water cut. Although the well is capable of producing at a of 500+ bbls/day, the production rate is being kept low deliberately to try to prevent premature water coning. Cumulative production exceeded 50,000 bbls of oil by the end of April, 1997 and lead to the permitting and licensing of several dozen Dundee wells by project end. Twelve of these permits were for continued development of Crystal Field. Two long horizontal wells were drilled successfully in Crystal after the TOW 1-3, but were disappointing economically. Core and logs from the Dundee interval were recovered from a vertical borehole at the same surface location. The addition of several horizontal wells will likely add another 2 million bbls (or more) to the cumulative production of the field over the next few years. If other abandoned Dundee fields are re-developed in a similar manner, the additional oil produced could exceed 80 million barrels.

NONE

1998-04-01T23:59:59.000Z

249

Better practices and synthetic fluid improve drilling rates  

SciTech Connect

Improved drilling practices, combined with the use of olefin-based synthetic drilling fluids, have dramatically reduced drilling time and costs in a difficult drilling area in the Gulf of Mexico. In the South Pass area, Marathon Oil Co. and other operators have had wells with long drilling times and high costs. In addition to the two wells with record penetration rates, routine drilling rates have also increased from the use of synthetic mud and careful drilling practices. Through application of these improved drilling practices, 2,000--3,000 ft/day can be drilled routinely. Marathon achieves this goal by applying the experience gained on previous wells, properly training and involving the crews, and using innovative drilling systems. Improved drilling practices and systems are just one part of successful, efficient drilling. Rig site personnel are major contributors to safely and successfully drilling at high penetration rates for extended periods. The on site personnel must act as a team and have the confidence and proper mental attitude about what is going on downhole. The paper describes the drilling history in the South Pass area, the synthetic drilling fluid used, cuttings handling, hole cleaning, drilling practices, bottom hole assemblies, and lost circulation.

White, W. (Marathon Oil Co., Lafayette, LA (United States)); McLean, A.; Park, S. (M-I Drilling Fluids, Houston, TX (United States))

1995-02-20T23:59:59.000Z

250

Performance-Oriented Drilling Fluids Design System with a Neural Network Approach  

Science Journals Connector (OSTI)

Drilling fluids play a key role in the minimization of well bore problems when drilling oil or gas wells, usually the design of drilling fluids is depended on many experiments with experience. Rule-based and case-based reasoning drilling fluid system ... Keywords: artificial neural network, drilling fluid, performance-oriented

Yongbin Zhang; Yeli Li; Peng Cao

2009-11-01T23:59:59.000Z

251

Chapter 2 - Offshore Oil and Gas Drilling Engineering and Equipment  

Science Journals Connector (OSTI)

Abstract This chapter introduces the drilling engineering and equipment in the field of offshore oil and gas.It starts by introducing the drilling platform used in the offshore oil and gas. Then it presents the wellhead and wellhead devices used in the offshore oil and gas. After these two, it begins to introduce the drilling engineer including preparation, working procedure, well completion and so on. Finally, it roughly introduces the new technology in drilling and new drilling rig nowadays.

Huacan Fang; Menglan Duan

2014-01-01T23:59:59.000Z

252

Ordovician Red River {open_quotes}B{close_quotes}: Horizontal oil play in the southern Williston basin  

SciTech Connect

Recent application of horizontal drilling technology to the Ordovician Red River {open_quotes}B{close_quotes} zone in the southern Williston basin has resulted in a successful oil play, with more than 100 wells drilled in 1995 and 1996. The Red River {open_quotes}B{close_quotes} reservoir is a dolomitized laminated carbonate with microsucrosic porosity of 8-25% and permeabilities in the range of 1-66 md. It occurs within the middle of three depositional cycles ({open_quotes}A,{close_quotes} {open_quotes}B,{close_quotes} and {open_quotes}C{close_quotes}) that form the upper Red River Formation. Each cycle consists of a lower burrowed limestone, middle laminated member, and capping anhydrite or lime mudstone. The {open_quotes}B{close_quotes} reservoir is confined to the {open_quotes}B{close_quotes} laminated member and consists of an upper portion, characterized by better reservoir quality, and a lower, less permeable portion. Horizontal drilling has the advantage of significantly increasing well-bore exposure to the upper, more permeable portion. Well data indicate the total Red River {open_quotes}B{close_quotes} porosity zone has remarkable extent over parts of southwestern North Dakota, southeastern Montana, and northwestern South Dakota. Productivity from horizontal well displays considerable variation that can be correlated with structure/tectonic patterns and with reservoir petrophysical character.

Montgomery, S.L.

1997-04-01T23:59:59.000Z

253

Horizontal Advanced Tensiometer  

DOE Patents (OSTI)

An horizontal advanced tensiometer is described that allows the monitoring of the water pressure of soil positions, particularly beneath objects or materials that inhibit the use of previous monitoring wells. The tensiometer includes a porous cup, a pressure transducer (with an attached gasket device), an adaptive chamber, at least one outer guide tube which allows access to the desired horizontal position, a transducer wire, a data logger and preferably an inner guide tube and a specialized joint which provides pressure on the inner guide tube to maintain the seal between the gasket of the transducer and the adaptive chamber.

Hubbell, Joel M.; Sisson, James B.

2004-06-22T23:59:59.000Z

254

Optimizing drilling performance using a selected drilling fluid  

DOE Patents (OSTI)

To improve drilling performance, a drilling fluid is selected based on one or more criteria and to have at least one target characteristic. Drilling equipment is used to drill a wellbore, and the selected drilling fluid is provided into the wellbore during drilling with the drilling equipment. The at least one target characteristic of the drilling fluid includes an ability of the drilling fluid to penetrate into formation cuttings during drilling to weaken the formation cuttings.

Judzis, Arnis (Salt Lake City, UT); Black, Alan D. (Coral Springs, FL); Green, Sidney J. (Salt Lake City, UT); Robertson, Homer A. (West Jordan, UT); Bland, Ronald G. (Houston, TX); Curry, David Alexander (The Woodlands, TX); Ledgerwood, III, Leroy W. (Cypress, TX)

2011-04-19T23:59:59.000Z

255

petroleum-cut (drilling) mud  

Science Journals Connector (OSTI)

petroleum-cut (drilling) mud, oil cut (drilling) mud [Drilling mud unintentionally admixed with crude oil, may result from oil entering the mud while drilling or from a drill-stem test of an oil rese...

2014-08-01T23:59:59.000Z

256

DEVELOPMENT AND TESTING OF UNDERBALANCED DRILLING PRODUCTS. Final Report, Oct 1995 - July 2001  

SciTech Connect

Underbalanced drilling is experiencing growth at a rate that rivals that of horizontal drilling in the mid-1980s and coiled-tubing drilling in the 1990s. Problems remain, however, for applying underbalanced drilling in a wider range of geological settings and drilling environments. This report addresses developments under this DOE project to develop products aimed at overcoming these problems. During Phase I of the DOE project, market analyses showed that up to 12,000 wells per year (i.e., 30% of all wells) will be drilled underbalanced in the U.S.A. within the next ten years. A user-friendly foam fluid hydraulics model (FOAM) was developed for a PC Windows environment during Phase I. FOAM predicts circulating pressures and flow characteristics of foam fluids used in underbalanced drilling operations. FOAM is based on the best available mathematical models, and was validated through comparison to existing models, laboratory test data and field data. This model does not handle two-phase flow or air and mist drilling where the foam quality is above 0.97. This FOAM model was greatly expanded during Phase II including adding an improved foam rheological model and a ''matching'' feature that allows the model to be field calibrated. During Phase I, a lightweight drilling fluid was developed that uses hollow glass spheres (HGS) to reduce the density of the mud to less than that of water. HGS fluids have several advantages over aerated fluids, including they are incompressible, they reduce corrosion and vibration problems, they allow the use of mud-pulse MWD tools, and they eliminate high compressor and nitrogen costs. Phase II tests showed that HGS significantly reduce formation damage with water-based drilling and completion fluids and thereby potentially can increase oil and gas production in wells drilled with water-based fluids. Extensive rheological testing was conducted with HGS drilling and completion fluids during Phase II. These tests showed that the HGS fluids act similarly to conventional fluids and that they have potential application in many areas, including underbalanced drilling, completions, and riserless drilling. Early field tests under this project are encouraging. These led to limited tests by industry (which are also described). Further field tests and cost analyses are needed to demonstrate the viability of HGS fluids in different applications. Once their effectiveness is demonstrated, they should find widespread application and should significantly reduce drilling costs and increase oil and gas production rates. A number of important oilfield applications for HGS outside of Underbalanced Drilling were identified. One of these--Dual Gradient Drilling (DGD) for deepwater exploration and development--is very promising. Investigative work on DGD under the project is reported, along with definition of a large joint-industry project resulting from the work. Other innovative products/applications are highlighted in the report including the use of HGS as a cement additive.

William C. Maurer; William J. McDonald; Thomas E. Williams; John H. Cohen

2001-07-01T23:59:59.000Z

257

Petroleum well costs.  

E-Print Network (OSTI)

??This is the first academic study of well costs and drilling times for Australia??s petroleum producing basins, both onshore and offshore. I analyse a substantial… (more)

Leamon, Gregory Robert

2006-01-01T23:59:59.000Z

258

Analysis of drill stem test data  

E-Print Network (OSTI)

constructed to illustrate the effects of changes in Kh/p, , well bore damage, and pro duction rate on the geometry of the drill stem test pressure buildup curve. To formulate the hypothetical drill stem test, certain reser- voir rock and fluid properties... constructed to illustrate the effects of changes in Kh/p, , well bore damage, and pro duction rate on the geometry of the drill stem test pressure buildup curve. To formulate the hypothetical drill stem test, certain reser- voir rock and fluid properties...

Zak, Albin Joseph

2012-06-07T23:59:59.000Z

259

Portable drilling mud system  

SciTech Connect

A portable well drilling mud storage and recirculation unit includes a mud storage tank mounted on an over-the-road semi-trailer having an engine driven circulating pump mounted onboard and adapted to withdraw mud from the tank for circulation to the well and for recirculation through a set of mud agitating nozzles disposed in the bottom of the tank. A mud degassing vessel, a solids separator unit and an additive blending unit are all mounted above the tank. The degassing vessel is supported by hydraulic cylinder actuators for movement between a retracted transport position and a vertically elevated working position.

Etter, R. W.; Briggs, J. M.

1984-10-02T23:59:59.000Z

260

HIGH-POWER TURBODRILL AND DRILL BIT FOR DRILLING WITH COILED TUBING  

SciTech Connect

Commercial introduction of Microhole Technology to the gas and oil drilling industry requires an effective downhole drive mechanism which operates efficiently at relatively high RPM and low bit weight for delivering efficient power to the special high RPM drill bit for ensuring both high penetration rate and long bit life. This project entails developing and testing a more efficient 2-7/8 in. diameter Turbodrill and a novel 4-1/8 in. diameter drill bit for drilling with coiled tubing. The high-power Turbodrill were developed to deliver efficient power, and the more durable drill bit employed high-temperature cutters that can more effectively drill hard and abrasive rock. This project teams Schlumberger Smith Neyrfor and Smith Bits, and NASA AMES Research Center with Technology International, Inc (TII), to deliver a downhole, hydraulically-driven power unit, matched with a custom drill bit designed to drill 4-1/8 in. boreholes with a purpose-built coiled tubing rig. The U.S. Department of Energy National Energy Technology Laboratory has funded Technology International Inc. Houston, Texas to develop a higher power Turbodrill and drill bit for use in drilling with a coiled tubing unit. This project entails developing and testing an effective downhole drive mechanism and a novel drill bit for drilling 'microholes' with coiled tubing. The new higher power Turbodrill is shorter, delivers power more efficiently, operates at relatively high revolutions per minute, and requires low weight on bit. The more durable thermally stable diamond drill bit employs high-temperature TSP (thermally stable) diamond cutters that can more effectively drill hard and abrasive rock. Expectations are that widespread adoption of microhole technology could spawn a wave of 'infill development' drilling of wells spaced between existing wells, which could tap potentially billions of barrels of bypassed oil at shallow depths in mature producing areas. At the same time, microhole coiled tube drilling offers the opportunity to dramatically cut producers' exploration risk to a level comparable to that of drilling development wells. Together, such efforts hold great promise for economically recovering a sizeable portion of the estimated remaining shallow (less than 5,000 feet subsurface) oil resource in the United States. The DOE estimates this U.S. targeted shallow resource at 218 billion barrels. Furthermore, the smaller 'footprint' of the lightweight rigs utilized for microhole drilling and the accompanying reduced drilling waste disposal volumes offer the bonus of added environmental benefits. DOE analysis shows that microhole technology has the potential to cut exploratory drilling costs by at least a third and to slash development drilling costs in half.

Robert Radtke; David Glowka; Man Mohan Rai; David Conroy; Tim Beaton; Rocky Seale; Joseph Hanna; Smith Neyrfor; Homer Robertson

2008-03-31T23:59:59.000Z

Note: This page contains sample records for the topic "horizontal wells drilling" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


261

Lateral drilling and completion technologies for shallow-shelf carbonates of the Red River and Ratcliffe Formations, Williston Basin. Topical report, July 1997  

SciTech Connect

Luff Exploration Company (LEC) focused on involvement in technologies being developed utilizing horizontal drilling concepts to enhance oil-well productivity starting in 1992. Initial efforts were directed toward high-pressure lateral jetting techniques to be applied in existing vertical wells. After involvement in several failed field attempts with jetting technologies, emphasis shifted to application of emerging technologies for drilling short-radius lateral in existing wellbores and medium-radius technologies in new wells. These lateral drilling technologies were applied in the Mississippi Ratcliffe and Ordovician Red River formations at depths of 2,590 to 2,890 m in Richland County, MT; Bowman County, ND; and Harding County, SD. In theory, all of the horizontal drilling techniques explored in this project have merit for application fitting specific criteria. From a realistic point of view, the only relatively trouble-free, adequately-proven technology employed was the medium-radius steered motor/MWD technology. The slim-tool steered motor/MWD re-entry technology has been used extensively but appears to still be significantly in developmental stages. This technology will probably always be more troublesome than the technology used to drill new wells because the smaller diameter required for the tools contributes to both design and operational complexities. Although limited mechanical success has been achieved with some of the lateral jetting technologies and the Amoco tools, their predictability and reliability is unproven. Additionally, they appear to be limited to shallow depths and certain rock types. The Amoco technology probably has the most potential to be successfully developed for routinely reliable, field applications. A comparison of the various horizontal drilling technologies investigated is presented.

Carrell, L.A.; George, R.D.; Gibbons, D.

1998-07-01T23:59:59.000Z

262

Rotary blasthole drilling update  

SciTech Connect

Blasthole drilling rigs are the unsung heroes of open-pit mining. Recently manufacturers have announced new tools. Original equipment manufactures (OEMs) are making safer and more efficient drills. Technology and GPS navigation systems are increasing drilling accuracy. The article describes features of new pieces of equipment: Sandvik's DR460 rotary blasthole drill, P & H's C-Series drills and Atlas Copco's Pit Viper PV275 multiphase rotary blasthole drill rig. DrillNav Plus is a blasthole navigation system developed by Leica Geosystems. 5 photos.

Fiscor, S.

2008-02-15T23:59:59.000Z

263

RAPID/Geothermal/Well Field/California | Open Energy Information  

Open Energy Info (EERE)

& Well Field Permit Agency: California Department of Conservation, Division of Oil, Gas, and Geothermal Resources Drilling & Well Field Permit Before drilling can commense,...

264

Geothermal drilling technology update  

SciTech Connect

Sandia National Laboratories conducts a comprehensive geothermal drilling research program for the US Department of Energy, Office of Geothermal Technologies. The program currently includes seven areas: lost circulation technology, hard-rock drill bit technology, high-temperature instrumentation, wireless data telemetry, slimhole drilling technology, Geothermal Drilling Organization (GDO) projects, and drilling systems studies. This paper describes the current status of the projects under way in each of these program areas.

Glowka, D.A.

1997-04-01T23:59:59.000Z

265

Biodegradation of Fuel Oil Hydrocarbons in Soil Contaminated by Oily Wastes Produced During Onshore Drilling Operations  

Science Journals Connector (OSTI)

The petroleum industry generates high amount of oily wastes during drilling, storage and refining operations. Onshore drilling operations produce oil based wastes, typically 100–150m-3 well. The drilling cuttings...

Qaude-Henri Chaîneau; Jean-Louis Morel; Jean Oudot

1995-01-01T23:59:59.000Z

266

Learning by Drilling: Inter-Firm Learning and Relationship Persistence in the Texas Oilpatch  

E-Print Network (OSTI)

frequency data from oil and gas drilling. I find that thean examination of the oil and gas drilling industry. I findintegration. The oil and gas drilling industry is well-

KELLOGG, RYAN M

2007-01-01T23:59:59.000Z

267

The Importance of Rheology in the Determination of the Carrying Capacity of Oil-Drilling Fluids  

Science Journals Connector (OSTI)

The ability of a drilling fluid to convey drill cuttings from a well is not fully ... cuttings travel with a lower velocity than the drilling fluid and they can accumulate in the ... lead to degradation of the cu...

M. A. Lockyer; J. M. Davies; T. E. R. Jones

1980-01-01T23:59:59.000Z

268

NNSA Small Business Week Day 2: United Drilling, Inc. | National...  

National Nuclear Security Administration (NNSA)

Inc., a small minority-owned business based in Roswell, N.M. United Drilling drills oil, gas, water, geothermal, and environmental wells throughout the southwestern U.S. The...

269

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

SciTech Connect

Implementation of the work program of Budget Period 2 of the East Binger Unit (''EBU'') DOE Project continues. Major development work planned for the project includes the drilling of three horizontal production and one vertical injection wells, the conversion of five wells from production to injection service, and the expansion of injection capacity at the nitrogen management facility. Other work items include initiation of project monitoring and continued reservoir simulation. EBU 74G-2, the injection well planned to support the production of EBU 64-3H, has been drilled. Completion was underway at the time of this report. EBU 64-3H was fracture-stimulated during the period, further increasing production from this new horizontal well. Drilling of the final two wells of the pilot project is planned for 2003. Both are planned as horizontal producing wells. Work also began on projects aimed at increasing injection in the pilot area. The project to add compression and increase injection capacity at the nitrogen management facility was initiated, with completion targeted for March 2003. Additional producer-to-injector conversions are expected to be implemented around the same time. The revised history match of the simulation model has been completed, and work has begun to evaluate options with forecast simulations. The quality of the history match is significantly improved over the prior match. The predicted distribution of remaining reserves in the field is significantly changed. Decisions on projects planned for implementation later in Budget Period 2 will be guided by new forecasts.

Joe Sinner

2003-01-31T23:59:59.000Z

270

Performance of hydraulic fracturing and matrix acidizing in horizontal wellbores -- Offshore Qatar  

SciTech Connect

Considerable debate in the Middle East has centered upon what was previously felt to be two separate methods of enhancing revenues and daily production; hydraulic fracturing and horizontal drilling. In an effort to maximize return on investment, these two issues have been successfully combined in other areas of the world. In order to establish the suitability of this technology in this area, two horizontal wells with over 3,050m (10,000ft) of lateral section were drilled into the Cretaceous Kharaib formation, overlying the North Field, Offshore Qatar. A massive stimulation program was performed in order to evaluate the most feasible stimulation method from both a technical and economical perspective for further field development considerations.Three propped hydraulic fracturing treatments were performed using 183, 500kg (403, 700lb) of 20/40 mesh sand, and seventeen acid matrix treatments placing over 3,217,250l (850,000gals) of HCL into the lateral sections of both wells. This paper describes the performance, operation and logistical support required to complete this offshore operation with join a minimal time frame. The use of a mobile offshore jack-up platform, whereby a land based fracturing spread was placed onto the deck of a converted drilling rig is described.

Edwards, M.G.R.; Pongratz, R.

1995-11-01T23:59:59.000Z

271

Determining root causes of drilling problems by combining cases and general knowledge  

E-Print Network (OSTI)

-based, knowledge intensive, oil well drilling 1 Introduction Drilling of oil wells is an expensive offshore based reasoning to improve efficiency of oil well drilling. Their focus was on lost circulation, whichDetermining root causes of drilling problems by combining cases and general knowledge Samad

Aamodt, Agnar

272

Improved Miscible Nitrogen Flood Performance Utilizing Advanced Reservoir Characterization and Horizontal Laterals in a Class I Reservoir--East Binger (Marchand) Unit  

SciTech Connect

A significant work program was implemented from 2002 to 2004 in the East Binger Unit (''EBU'') miscible nitrogen injection project in an effort to reduce gas cycling and economically increase ultimate oil recovery. This work included the drilling of new wells, both horizontal and vertical, as well as pattern realignment through producer-to-injector conversions. Monitoring of overall performance of the pilot area continues. Response to the various projects continues to be very favorable. Injection into the pilot area, though limited at times by problems in the Air Separation Unit of the Nitrogen Management Facility, and has increased 70% over levels prior to the project. Meanwhile, gas production and nitrogen content of produced gas have both decreased. Nitrogen recycle within the pilot area is now only about 32%, far below the 72% recycle prior to initiation of the project. Poor areal sweep efficiency appears to be the primary cause of nitrogen cycling. Four vertical and three horizontal wells have been drilled in the pilot area throughout the project, and most have had initial produced gas oil ratios and gas nitrogen contents significantly below the field averages. Additional vertical well drilling is planned due to the success of wells drilled to date.

Joe Sinner

2005-09-15T23:59:59.000Z

273

Application of short-radius horizontal boreholes in the naturally fractured Yates field  

SciTech Connect

This paper discusses the performance and simulation of short-radius horizontal boreholes being used in the Marathon-operated Yates field Unit in west Texas to minimize drawdown and therefore to reduce gas and water coning in a thin oil column. Yates is a very prolific field with extensive fracturing and high-quality reservoir rock. Superimposed on a high-density orthogonal fracture network are widely spaced regional joints with a strong directional tendency. Major questions are how these directional joints affect the horizontal-well performance and whether wells should be drilled parallel or perpendicular to the joints. Dual-permeability reservoir simulation studies were performed to study optimum orientation of the borehole with respect to the natural fracture network. Additionally, optimum well-completion elevation was studied. Forty-six vertical wells have been recompleted as short-radius horizontal boreholes since 1986. The large productivity increase of the horizontal boreholes compared with the previous vertical completions indicates that the wells are intersecting the regional joints.

Gilman, J.R.; Rothkopf, B.W. (Marathon Petroleum Technology Center, Littleton, CO (United States)); Bowzer, J.L. (Marathon Oil Co., Midland, TX (United States))

1995-02-01T23:59:59.000Z

274

Core Drilling Demonstration  

Energy.gov (U.S. Department of Energy (DOE))

Tank Farms workers demonstrate core drilling capabilities for Hanford single-shell tanks. Core drilling is used to determine the current condition of each tank to assist in the overall assessment...

275

Foam drilling simulator  

E-Print Network (OSTI)

Although the use of compressible drilling fluids is experiencing growth, the flow behavior and stability properties of drilling foams are more complicated than those of conventional fluids. In contrast with conventional mud, the physical properties...

Paknejad, Amir Saman

2007-04-25T23:59:59.000Z

276

DRILLING MACHINES GENERAL INFORMATION  

E-Print Network (OSTI)

or quill assembly. The head of the drill press is composed of the sleeve, spindle, electric motor, and feed

Gellman, Andrew J.

277

Productivity and Injectivity of Horizontal Wells  

SciTech Connect

The generation of suitable simulation grids for heterogeneous media and specific discretization issues that arise. Streamlines and equipotentials are used to define our base grids. Since streamlines are concentrated in high velocity regions they provide a natural means of clustering fine grid cells in crucial flow regions. For complex configurations and particularly for strongly heterogeneous regions the resulting grid cells can become very distorted due to extremely high curvatures. Two types of cell centered formulation are examined together with a cell vertex-point distributed scheme. Important distinctions are found for highly distorted cells. The new grids are tested for accuracy in terms of critical breakthrough parameters and it is shown that a much higher level of grid resolution is required by conventional simulators in order to achieve results that are comparable with those computed on relatively coarse streamline-potential grids.

Aziz, Khalid; Hewett, Thomas A.; Arbabi, Sepehr; Smith, Marilyn

1999-11-16T23:59:59.000Z

278

Coiled tubing drilling with supercritical carbon dioxide  

DOE Patents (OSTI)

A method for increasing the efficiency of drilling operations by using a drilling fluid material that exists as supercritical fluid or a dense gas at temperature and pressure conditions existing at a drill site. The material can be used to reduce mechanical drilling forces, to remove cuttings, or to jet erode a substrate. In one embodiment, carbon dioxide (CO.sub.2) is used as the material for drilling within wells in the earth, where the normal temperature and pressure conditions cause CO.sub.2 to exist as a supercritical fluid. Supercritical carbon dioxide (SC--CO.sub.2) is preferably used with coiled tube (CT) drilling equipment. The very low viscosity SC--CO.sub.2 provides efficient cooling of the drill head, and efficient cuttings removal. Further, the diffusivity of SC--CO.sub.2 within the pores of petroleum formations is significantly higher than that of water, making jet erosion using SC--CO.sub.2 much more effective than water jet erosion. SC--CO.sub.2 jets can be used to assist mechanical drilling, for erosion drilling, or for scale removal. A choke manifold at the well head or mud cap drilling equipment can be used to control the pressure within the borehole, to ensure that the temperature and pressure conditions necessary for CO.sub.2 to exist as either a supercritical fluid or a dense gas occur at the drill site. Spent CO.sub.2 can be vented to the atmosphere, collected for reuse, or directed into the formation to aid in the recovery of petroleum.

Kolle , Jack J. (Seattle, WA)

2002-01-01T23:59:59.000Z

279

Evaluation of high rotary speed drill bit performance  

E-Print Network (OSTI)

of this research was to develop a drilling model which would more accurately predict penetration rates with standard drilling parameters. An accurate model was developed using laboratory drilling performance. A secondary result of this research was a qualitative... analysis showed that the model may be used to qualita- tivelyy match drilled formations to offset well logs. The ratio of actual to predicted penetration rate was used in conjunction with the gamma ray log to correlate the location of formations. iv...

Ray, Randy Wayne

2012-06-07T23:59:59.000Z

280

Exploratory Well | Open Energy Information  

Open Energy Info (EERE)

Exploratory Well Exploratory Well Jump to: navigation, search GEOTHERMAL ENERGYGeothermal Home Exploration Technique: Exploratory Well Details Activities (8) Areas (3) Regions (0) NEPA(5) Exploration Technique Information Exploration Group: Drilling Techniques Exploration Sub Group: Exploration Drilling Parent Exploration Technique: Exploration Drilling Information Provided by Technique Lithology: Can provide core or cuttings Stratigraphic/Structural: Identify stratigraphy and structural features within a well Hydrological: -Water samples can be used for geochemical analysis -Fluid pressures can be used to estimate flow rates Thermal: -Temperatures can be measured within the hole -Information about the heat source Dictionary.png Exploratory Well: An exploratory well is drilled for the purpose of identifying the

Note: This page contains sample records for the topic "horizontal wells drilling" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


281

Development and Testing of Insulated Drill Pipe  

SciTech Connect

This project has comprised design, analysis, laboratory testing, and field testing of insulated drill pipe (IDP). This paper will briefly describe the earlier work, but will focus on results from the recently-completed field test in a geothermal well. Field test results are consistent with earlier analyses and laboratory tests, all of which support the conclusion that insulated drill pipe can have a very significant effect on circulating fluid temperatures. This will enable the use of downhole motors and steering tools in hot wells, and will reduce corrosion, deterioration of drilling fluids, and heat-induced failures in other downhole components.

Champness, T.; Finger, J.; Jacobson, R.

1999-07-07T23:59:59.000Z

282

Innovative technology summary report: Cryogenic drilling  

SciTech Connect

Environmental drilling is used to conduct site investigations and to install monitoring and remediation wells. Employing conventional drilling techniques to conduct environmental investigations in unconsolidated soils can result in borehole collapse and may also lead to cross-contamination of aquifers and soil formations. For investigations in certain geologic conditions, there are currently no viable conventional drilling techniques available. Cryogenic drilling improves upon conventional air rotary drilling by replacing ambient air with cold nitrogen (either liquid or gas) as the circulating medium. The cold nitrogen gas stream freezes moisture in the ground surrounding the hole. The frozen zone prevents the collapse of the hole and prevents the movement of groundwater or contaminants through and along the hole. The technology, its performance, uses, cost, and regulatory issues are discussed.

NONE

1998-10-01T23:59:59.000Z

283

Limitations of extended reach drilling in deepwater  

E-Print Network (OSTI)

As the worldwide search for hydrocarbons continues into the deepwater of the oceans, drilling extended reach wells have helped to drain the fields in the most cost effective way, thus providing the oil and gas industry the cushion to cope...

Akinfenwa, Akinwunmi Adebayo

2012-06-07T23:59:59.000Z

284

Handbook of Best Practices for Geothermal Drilling  

Energy.gov (U.S. Department of Energy (DOE))

This handbook focuses on the complex process of drilling a geothermal well, including techniques and hardware that have proven successful for both direct use and electricity generation around the world.

285

Production Wells | Open Energy Information  

Open Energy Info (EERE)

Production Wells Production Wells (Redirected from Development Wells) Jump to: navigation, search GEOTHERMAL ENERGYGeothermal Home Exploration Technique: Production Wells Details Activities (13) Areas (13) Regions (0) NEPA(7) Exploration Technique Information Exploration Group: Drilling Techniques Exploration Sub Group: Development Drilling Parent Exploration Technique: Development Drilling Information Provided by Technique Lithology: Drill cuttings are analyzed to determine lithology and mineralogy Stratigraphic/Structural: Fractures, faults, and geologic formations that the well passes through are identified and mapped. Hydrological: Identify aquifers, reservoir boundaries, flow rates, fluid pressure, and chemistry Thermal: Direct temperature measurements from within the reservoir

286

Production Wells | Open Energy Information  

Open Energy Info (EERE)

Production Wells Production Wells Jump to: navigation, search GEOTHERMAL ENERGYGeothermal Home Exploration Technique: Production Wells Details Activities (13) Areas (13) Regions (0) NEPA(7) Exploration Technique Information Exploration Group: Drilling Techniques Exploration Sub Group: Development Drilling Parent Exploration Technique: Development Drilling Information Provided by Technique Lithology: Drill cuttings are analyzed to determine lithology and mineralogy Stratigraphic/Structural: Fractures, faults, and geologic formations that the well passes through are identified and mapped. Hydrological: Identify aquifers, reservoir boundaries, flow rates, fluid pressure, and chemistry Thermal: Direct temperature measurements from within the reservoir Dictionary.png Production Wells:

287

Well Deepening | Open Energy Information  

Open Energy Info (EERE)

Well Deepening Well Deepening Jump to: navigation, search GEOTHERMAL ENERGYGeothermal Home Exploration Technique: Well Deepening Details Activities (5) Areas (3) Regions (0) NEPA(0) Exploration Technique Information Exploration Group: Drilling Techniques Exploration Sub Group: Development Drilling Parent Exploration Technique: Development Drilling Information Provided by Technique Lithology: Drill cuttings are analyzed to determine lithology and mineralogy Stratigraphic/Structural: Fractures, faults, and geologic formations that the well passes through are identified and mapped. Hydrological: Identify aquifers, reservoir boundaries, flow rates, fluid pressure, and chemistry Thermal: Direct temperature measurements from within the reservoir Dictionary.png Well Deepening:

288

HP-41CV applied drilling engineering manual  

SciTech Connect

Contents of this manual are as follows: average diameter of an open hole; pump cycle, pump factor, and annulus capacity; drilling-time and penetration rate predictions; nozzle selection; direction well survey; viscosity of drilling fluids; barite requirements with solids dilution; solids analysis and recommended flow properties; evaluation of hydrocyclones; frictional pressure loss; surge and swab pressures; pressure and average density of a gas column; cement additive requirements; kick tolerance, severity, length and density; and pump pressure schedule for well control operations.

Chenevert, M.; Williams, F.; Hekimian, H.

1983-01-01T23:59:59.000Z

289

A new type of whole oil-based drilling fluid  

Science Journals Connector (OSTI)

Abstract To meet the demand of ultra-deep well drilling and shale gas well drilling, organic clay and a oil-based filtrate reducer were developed and a whole oil-based drilling fluid formula was optimized. The performance of organic clay, oil-based filtrate reducer and the whole oil-based drilling fluid were evaluated in laboratory, and the whole oil-based drilling fluid was applied in drilling process for further test of its performance. Long carbon chain quaternary ammonium salt was used as modifying agents when synthesizing organobentonites. Oil-based filtrate reducer was synthesized with monomers of lignite and amine class. The laboratory tests show that the organic clay can effectively increase the viscosity of oil-based drilling fluid and the oil-based filtrate reducer can reduce the fluid loss. Their performances were better than additives of the same kind at home and abroad. The organic clay and oil-based filtrate reducer had great compatibility with the other additives in oil-based drilling fluid. Based on the optimal additives addition amount tests, the whole oil-based drilling fluid formula was determined and the test results show that the performances of the whole oil-based drilling fluids with various densities were great. The laboratory tests show that the oil-based drilling fluid developed was high temperature resistant, even at 200 °C, as density varies from 0.90 to 2.0 g/cm3, it still held good performance with only a little fluid loss, good inhibition, great anti-pollution, and good reservoir protection performance. Field application result shows that the performance of the oil-based drilling fluid is stable with great ability to maintain wellbore stability and lower density than the water-based drilling fluid; drilling bits can be used much longer and the average penetration rate is increased; the oil-based drilling fluid can satisfy the drilling requirements.

Jiancheng LI; Peng YANG; Jian GUAN; Yande SUN; Xubing KUANG; Shasha CHEN

2014-01-01T23:59:59.000Z

290

Method of deep drilling  

DOE Patents (OSTI)

Deep drilling is facilitated by the following steps practiced separately or in any combination: (1) Periodically and sequentially fracturing zones adjacent the bottom of the bore hole with a thixotropic fastsetting fluid that is accepted into the fracture to overstress the zone, such fracturing and injection being periodic as a function of the progression of the drill. (2) Casing the bore hole with ductile, pre-annealed casing sections, each of which is run down through the previously set casing and swaged in situ to a diameter large enough to allow the next section to run down through it. (3) Drilling the bore hole using a drill string of a low density alloy and a high density drilling mud so that the drill string is partially floated.

Colgate, Stirling A. (4616 Ridgeway, Los Alamos, NM 87544)

1984-01-01T23:59:59.000Z

291

Hydraulic fracturing slurry transport in horizontal pipes  

SciTech Connect

Horizontal-well activity has increased throughout the industry in the past few years. To design a successful hydraulic fracturing treatment for horizontal wells, accurate information on the transport properties of slurry in horizontal pipe is required. Limited information exists that can be used to estimate critical deposition and resuspension velocities when proppants are transported in horizontal wells with non-Newtonian fracturing gels. This paper presents a study of transport properties of various hydraulic fracturing slurries in horizontal pipes. Flow data are gathered in three transparent horizontal pipes with different diameters. Linear and crosslinked fracturing gels were studied, and the effects of variables--e.g., pipe size; polymer-gelling-agent concentration; fluid rheological properties; crosslinking effects; proppant size, density, and concentrations; fluid density; and slurry pump rate--on critical deposition and resuspension velocities were investigated. Also, equations to estimate the critical deposition and resuspension velocities of fracturing gels are provided.

Shah, S.N.; Lord, D.L. (Halliburton Services (US))

1990-09-01T23:59:59.000Z

292

Counter-Rotating Tandem Motor Drilling System  

SciTech Connect

Gas Technology Institute (GTI), in partnership with Dennis Tool Company (DTC), has worked to develop an advanced drill bit system to be used with microhole drilling assemblies. One of the main objectives of this project was to utilize new and existing coiled tubing and slimhole drilling technologies to develop Microhole Technology (MHT) so as to make significant reductions in the cost of E&P down to 5000 feet in wellbores as small as 3.5 inches in diameter. This new technology was developed to work toward the DOE's goal of enabling domestic shallow oil and gas wells to be drilled inexpensively compared to wells drilled utilizing conventional drilling practices. Overall drilling costs can be lowered by drilling a well as quickly as possible. For this reason, a high drilling rate of penetration is always desired. In general, high drilling rates of penetration (ROP) can be achieved by increasing the weight on bit and increasing the rotary speed of the bit. As the weight on bit is increased, the cutting inserts penetrate deeper into the rock, resulting in a deeper depth of cut. As the depth of cut increases, the amount of torque required to turn the bit also increases. The Counter-Rotating Tandem Motor Drilling System (CRTMDS) was planned to achieve high rate of penetration (ROP) resulting in the reduction of the drilling cost. The system includes two counter-rotating cutter systems to reduce or eliminate the reactive torque the drillpipe or coiled tubing must resist. This would allow the application of maximum weight-on-bit and rotational velocities that a coiled tubing drilling unit is capable of delivering. Several variations of the CRTDMS were designed, manufactured and tested. The original tests failed leading to design modifications. Two versions of the modified system were tested and showed that the concept is both positive and practical; however, the tests showed that for the system to be robust and durable, borehole diameter should be substantially larger than that of slim holes. As a result, the research team decided to complete the project, document the tested designs and seek further support for the concept outside of the DOE.

Kent Perry

2009-04-30T23:59:59.000Z

293

Geothermal Drilling Organization  

SciTech Connect

The Geothermal Drilling Organization (GDO), founded in 1982 as a joint Department of Energy (DOE)-Industry organization, develops and funds near-term technology development projects for reducing geothermal drilling costs. Sandia National Laboratories administers DOE funds to assist industry critical cost-shared projects and provides development support for each project. GDO assistance to industry is vital in developing products and procedures to lower drilling costs, in part, because the geothermal industry is small and represents a limited market.

Sattler, A.R.

1999-07-07T23:59:59.000Z

294

Gel Evolution in Oil Based Drilling Fluids.  

E-Print Network (OSTI)

?? Drilling fluids make up an essential part of the drilling operation. Successful drilling operations rely on adequate drilling fluid quality. With the development of… (more)

Sandvold, Ida

2012-01-01T23:59:59.000Z

295

Training and Drills  

Directives, Delegations, and Requirements

The volume offers a framework for effective management of emergency response training and drills. Canceled by DOE G 151.1-3.

1997-08-21T23:59:59.000Z

296

Remote drill bit loader  

DOE Patents (OSTI)

A drill bit loader for loading a tapered shank of a drill bit into a similarly tapered recess in the end of a drill spindle. The spindle has a transverse slot at the inner end of the recess. The end of the tapered shank of the drill bit has a transverse tang adapted to engage in the slot so that the drill bit will be rotated by the spindle. The loader is in the form of a cylinder adapted to receive the drill bit with the shank projecting out of the outer end of the cylinder. Retainer pins prevent rotation of the drill bit in the cylinder. The spindle is lowered to extend the shank of the drill bit into the recess in the spindle and the spindle is rotated to align the slot in the spindle with the tang on the shank. A spring unit in the cylinder is compressed by the drill bit during its entry into the recess of the spindle and resiliently drives the tang into the slot in the spindle when the tang and slot are aligned.

Dokos, James A. (Idaho Falls, ID)

1997-01-01T23:59:59.000Z

297

Remote drill bit loader  

DOE Patents (OSTI)

A drill bit loader is described for loading a tapered shank of a drill bit into a similarly tapered recess in the end of a drill spindle. The spindle has a transverse slot at the inner end of the recess. The end of the tapered shank of the drill bit has a transverse tang adapted to engage in the slot so that the drill bit will be rotated by the spindle. The loader is in the form of a cylinder adapted to receive the drill bit with the shank projecting out of the outer end of the cylinder. Retainer pins prevent rotation of the drill bit in the cylinder. The spindle is lowered to extend the shank of the drill bit into the recess in the spindle and the spindle is rotated to align the slot in the spindle with the tang on the shank. A spring unit in the cylinder is compressed by the drill bit during its entry into the recess of the spindle and resiliently drives the tang into the slot in the spindle when the tang and slot are aligned. 5 figs.

Dokos, J.A.

1997-12-30T23:59:59.000Z

298

Attenuation of sound waves in drill strings  

Science Journals Connector (OSTI)

During drilling of deep wells digital data are often transmitted from sensors located near the drill bit to the surface. Development of a new communication system with increased data capacity is of paramount importance to the drilling industry. Since steel drill strings are used transmission of these data by elastic carrier waves traveling within the drill pipe is possible but the potential communication range is uncertain. The problem is complicated by the presence of heavy?threaded tool joints every 10 m which form a periodic structure and produce classical patterns of passbands and stop bands in the wave spectra. In this article field measurements of the attenuation characteristics of a drill string in the Long Valley Scientific Well in Mammoth Lakes California are presented. Wave propagation distances approach 2 km. A theoretical model is discussed which predicts the location width and attenuation of the passbands. Mode conversion between extensional and bending waves and spurious reflections due to deviations in the periodic spacings of the tool joints are believed to be the sources of this attenuation. It is estimated that attenuation levels can be dramatically reduced by rearranging the individual pipes in the drill string according to length.

Douglas S. Drumheller

1993-01-01T23:59:59.000Z

299

Deep Drilling Basic Research: Volume 5 - System Evaluations. Final Report, November 1988--August 1990  

SciTech Connect

This project is aimed at decreasing the costs and increasing the efficiency of drilling gas wells in excess of 15,000 feet. This volume presents a summary of an evaluation of various drilling techniques. Drilling solutions were compared quantitatively against typical penetration rates derived from conventional systems. A qualitative analysis measured the impact of a proposed system on the drilling industry. The evaluations determined that the best candidates f o r improving the speed and efficiency of drilling deep gas wells include: PDC/TSD bits, slim-hole drilling, roller-cone bits, downhole motors, top-driven systems, and coiled-tubing drilling.

None

1990-06-01T23:59:59.000Z

300

Recovery of bypassed oil in the Dundee Formation using horizontal drains, Quarterly technical report, 1/1/97--3/31/97  

SciTech Connect

This Class 11 field project has demonstrated that economic quantities of hydrocarbons can be produced from abandoned or nearly abandoned fields in the Dundee Formation of Central Michigan using horizontal drilling technology. The site selected for the demonstration horizontal well was Crystal Field, a nearly abandoned Dundee oil field in Montcalm County, Michigan. This field had produced over 8 million barrels of oil, mostly in the 1930`s and 1940`s. At the height of development, Crystal Field produced from 193 wells, but by 1995, only seven producing wells remained, each producing less than 10 bbls/day. A horizontal well, the TOW 1-3, drilled as a field demonstration pilot was successful, producing at rate of 100 bbls of oil per day with a zero water cut. Although the well is capable of producing at a rate of 500+ bbls/day, the production rate is being kept low deliberately to try to prevent premature water coning. Cumulative production exceeded 50,000 bbls of oil by the end of April, 1997 and lead to the permitting and licensing of several dozen Dundee wells by project end. Twelve of these permits were for continued development of Crystal Field. Two subsequent wells, the Frost 5-3 and the Happy Holidays 6-3, have not been as successful. Both are currently producing 10 BOPD with 90% water cut. Efforts are underway to determine why these wells are performing so poorly and to see if the situation can be remedied. The reasons for these poor performances of the new wells are not clear at this time. It is possible that the wells entered the Dundee too low and missed pay higher in the section. When the TOW 1-3 was drilled, a vertical probe well was also drilled and cored. That probe well penetrated the pay zone and helped guide the horizontal well. The important lesson may be that vertical probe wells are a crucial step in producing these old fields and should not be eliminated simply to save what amounts to a small incremental cost. Core and logs from the Dundee interval were recovered from a vertical borehole at the same surface location. The addition of several horizontal wells will likely add another 2 million bbls (or more) to the cumulative production of the field over the next few years. If other abandoned Dundee fields are re-developed in a similar manner, the additional oil produced could exceed 80 million barrels. Additional project work involved the characterization of 28 other Dundee fields in Michigan to aid in determining appropriate additional candidates for development through horizontal drilling. Further quantification of reservoir parameters such as importance of fracturing, fracture density, and irregularity of the dolomitized surface at the top of the reservoir will help in designing the optimal strategy for horizontal drilling. The project was a cooperative venture involving the US Department of Energy, Michigan Technological University (MTU), Western Michigan University (WMU), and Terra Energy (now Cronus Development Co.) in Traverse City, MI.

NONE

1997-03-30T23:59:59.000Z

Note: This page contains sample records for the topic "horizontal wells drilling" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


301

Design and implementation of a CO{sub 2} flood utilizing advanced reservoir characterization and horizontal injection wells in a shallow shelf carbonate approaching waterflood depletion. Annual Report, July 1, 1995--June 30, 1996  

SciTech Connect

The work reported herein covers select tasks remaining in Budget Phase I and many of the tasks of Budget Phase II. The principal Tasks in Budget Phase I included in this report are Reservoir Analysis and Characterization; Advanced Technical Studies; and Technology Transfer, Reporting and Project Management Activities for Budget Phase I. The principle Task in Budget Phase II included in this report is Field Demonstration. Completion of these tasks has enabled an optimum carbon dioxide (CO{sub 2}) flood project to be designed, economically evaluated, and implemented in the field. Field implementation of the project commenced during late 1995, with actual CO{sub 2} injection scheduled for start-up in mid-July, 1996. The current project has focused on reducing initial investment cost by utilizing horizontal injection wells and concentrating the project in the best productivity area of the field. An innovative CO{sub 2} purchase agreement (no take-or-pay provisions, CO{sub 2} purchase price tied to West Texas Intermediate (WTI) crude oil price) and gas recycle agreements (expensing costs as opposed to a large upfront capital investment for compression) were negotiated to further improve the project economics. The Grayburg-San Andres section had previously been divided into multiple zones based on the core study and gamma ray markers that correlate wells within the Unit. Each zone was mapped as continuous across the field. Previous core studies concluded that the reservoir quality in the South Cowden Unit (SCU) is controlled primarily by the distribution of a bioturbated and diagenetically-altered rock type with a distinctive {open_quotes}chaotic{close_quotes} texture. The {open_quotes}chaotic{close_quotes} modifier is derived from the visual effect of pervasive, small-scale intermixing of tan oil-stained reservoir rock with tight gray non-reservoir rock.

Chimahusky, J.S.; Hallenbeck, L.D.; Harpole, K.J.; Dollens, K.B.

1997-05-01T23:59:59.000Z

302

Horizontal natural gas storage caverns and methods for producing same  

DOE Patents (OSTI)

The invention provides caverns and methods for producing caverns in bedded salt deposits for the storage of materials that are not solvents for salt. The contemplated salt deposits are of the bedded, non-domed variety, more particularly salt found in layered formations that are sufficiently thick to enable the production of commercially usefully sized caverns completely encompassed by walls of salt of the formation. In a preferred method, a first bore hole is drilled into the salt formation and a cavity for receiving insolubles is leached from the salt formation. Thereafter, at a predetermined distance away from the first bore hole, a second bore hole is drilled towards the salt formation. As this drill approaches the salt, the drill assumes a slant approach and enters the salt and drills through it in a horizontal direction until it intersects the cavity for receiving insolubles. This produces a substantially horizontal conduit from which solvent is controlledly supplied to the surrounding salt formation, leaching the salt and producing a concentrated brine which is removed through the first bore hole. Insolubles are collected in the cavity for receiving insolubles. By controlledly supplying solvent, a horizontal cavern is produced with two bore holes extending therefrom.

Russo, Anthony (Albuquerque, NM)

1995-01-01T23:59:59.000Z

303

Drilling continues upward momentum  

SciTech Connect

This paper discusses how the drilling recovery that began during the second half of 1989 is continuing into 1990. On top of this, the Iraqi invasion of Kuwait has caused disarray in oil markets, driving up oil prices, and disrupting access to oil supplies. Potentially, this upheaval could lead to an upward spike in worldwide drilling activity.

Moritis, G.

1990-09-24T23:59:59.000Z

304

Mobility for Offshore Drilling  

Science Journals Connector (OSTI)

Mobility for Offshore Drilling ... New type unit designed by Humble Oil to operate in Gulf of Mexico in 30 to 70 feet deep water ... HUMBLE OIL & REFINING is inviting bids on construction of a new type of mobile drilling platform to be used in offshore operations. ...

1956-03-26T23:59:59.000Z

305

OFFSHORE DRILLING REVISITED  

Science Journals Connector (OSTI)

OFFSHORE DRILLING REVISITED ... Congress and the Obama Administration weigh the benefits and risks of expanded OIL AND GAS PRODUCTION ... ENERGY INDUSTRY OFFICIALS, coastal states, and environmental activists are clashing over whether Congress and the Obama Administration should allow offshore drilling for oil and natural gas in federal waters that until last year were off limits to development. ...

GLENN HESS

2009-03-23T23:59:59.000Z

306

International guide: blasthole drills  

SciTech Connect

This survey is a comprehensive quick reference guide for surface mine operators. It details rotary blasthole drill rigs that are available around the world. More than 60 drills, each with a pulldown of about 125 kN, are included in the survey.

Chadwick, J.R.

1982-01-01T23:59:59.000Z

307

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

SciTech Connect

Implementation of the work program of Budget Period 2 of the East Binger Unit (''EBU'') DOE Project is progressing and nearing completion. Two of three planned horizontal wells have been drilled and completed. The third horizontal well will be replaced by two vertical wells, both of which will be drilled in early 2004. Based on costs and performances of all new wells, it is believed that, in the setting of the East Binger Unit, the benefits of horizontal wells do not justify the additional cost. In addition to the drilling of new wells, the project also includes conversions of producing wells to injection service. Four wells have now been converted, and injection in the pilot area has doubled. A fifth planned conversion has been removed from the project. Overall response to the various projects continues to be very favorable. Gas injection into the pilot area has increased from 4.0 MMscf/d prior to development to 8.0 MMscf/d in November, while gas production has decreased from 4.1 MMscf/d to 3.0 MMscf/d. The nitrogen content of produced gas has dropped from 58% to 45%. This has reduced the nitrogen recycle within the pilot area from 60% to under 20%. Meanwhile, pilot area oil production has increased, from 300 bpd prior to development to over 425 bpd in November 2003. This is down from 600 bopd in September because EBU 63-2H has begun to level off and other wells were temporarily down. This incremental rate will increase with the addition of the two vertical wells.

Joe Sinner

2004-02-24T23:59:59.000Z

308

Stress analysis of a hybrid composite drilling riser  

E-Print Network (OSTI)

. Validation and Verification of the Model. . . 33 35 38 RESULTS AND DISCUSSION . . 43 SUMMARY 49 Current Analysis . Future Work 49 50 REFERENCES . 52 APPENDIX A TABLES. 56 APPENDIX B FIGURES . . 68 APPENDIX C TENSOR TRANSFORMATIONS. . 107 VITA... serves as a conduit between the drilling platform and the subsea well- head. It provides a protected path for the tools being inserted into the well, and for the drilling mud that circulates from the drilling platform to the wefl bottom. The marine...

Sundstrom, Keith Andrew

1996-01-01T23:59:59.000Z

309

Titanium for Offshore Oil Drilling  

Science Journals Connector (OSTI)

Current and future applications for titanium and its alloys for offshore drilling have been examined. Successful applications were shown ... chlorination systems. Future applications especially for deepwater drilling

Dennis F. Hasson; C. Robert Crowe

1982-01-01T23:59:59.000Z

310

Focus on rotary drill rigs  

SciTech Connect

This article discusses the drill rig, focusing on the rotary drill rigs. There are two principal drilling methods - rotary and percussion. In certain situations, percussion drilling is the most practical method, but for most applications, rotary drilling using the rotary-tricone bit with either steel-toothed cones or carbide inserts, is the common and accepted drilling technique. There are four principal reasons for a rotary drill rig: to provide power to the rotary-tricone bit; to provide air to clean the hole; to provide a life-support system for the rotary-tricone bits; and, to provide a stable and efficient platform from which to drill the hole.

Schivley, G.P. Jr.

1987-06-01T23:59:59.000Z

311

U. S. Energy Information Administration | Drilling Productivity Report  

U.S. Energy Information Administration (EIA) Indexed Site

December 2013 December 2013 Explanatory notes Drilling Productivity Report The Drilling Productivity Report uses recent data on the total number of drilling rigs in operation along with estimates of drilling productivity and estimated changes in production from existing oil and natural gas wells to provide estimated changes in oil and natural gas production for six key fields. EIA's approach does not distinguish between oil-directed rigs and gas-directed rigs because once a well is completed it may produce both oil and gas; more than half of the wells do that. Monthly additions from one average rig Monthly additions from one average rig represent EIA's estimate of an average rig's

312

NEPA COMPLIANCE SURVEY Project Information Project Title: Liner Drilling Date:  

Energy.gov (U.S. Department of Energy (DOE)) Indexed Site

Liner Drilling Date: Liner Drilling Date: 4-5-10 DOE Code: 71092 Cont ractor Code: 8067-766 Project Lead: Frank Ingham Project Overview Nothing out of the ordinary for drilling an existing location 1. What are the environmental impacts? NE SW Sec 21 , T39N, R78W (45-3-X-21 well) 2. What is the legal location? 3. What is the duration of the project? Approximately a week 4 . What major equipment will be used if any (work over rig, drilling rig, Drilling Rig etc.)? Will Drill out of 9 5/8 caslng with liner drillng assembly. After drilling approximately 750 to 1000 ft, will test liner hanging assembly set and retrieve multiple times. The table b elow is to be completed by the Project Lead and reviewed by the Environmental Specialis t and the DOE NEPA Compliance Officer. NOTE: If Change of Scope occurs, Project Lead must submit a new NEPA Compliance Survey a

313

Design and implementation of a CO{sub 2} flood utilizing advanced reservoir characterization and horizontal injection wells in a shallow shelf carbonate approaching waterflood depletion. Annual report, June 3, 1994--October 31, 1995  

SciTech Connect

The work reported here covers Budget Phase I of the project. The principal tasks in Budget Phase I are the Reservoir Analysis and Characterization Task and the Advanced Technology Definition Task. Completion of these tasks have enabled an optimum carbon dioxide (CO{sub 2}) flood project to be designed and evaluated from an economic and risk analysis standpoint. Field implementation of the project has been recommended to the working interest owner of the South Cowden Unit (SCU) and approval has been obtained. The current project has focused on reducing initial investment cost by utilizing horizontal injection wells and concentrating the project in the best productivity area of the field. An innovative CO{sub 2} purchase agreement (no take or pay requirements, CO{sub 2} purchase price tied to West Texas Intermediate crude oil price) and gas recycle agreements (expensing cost as opposed to large capital investments for compression) were negotiated to further improve project economics. A detailed reservoir characterization study was completed by an integrated team of geoscientists and engineers. The study consisted of detailed core description, integration of log response to core descriptions, mapping of the major flow units, evaluation of porosity and permeability relationships, geostatistical analysis of permeability trends, and direct integration of reservoir performance with the geological interpretation. The study methodology fostered iterative bidirectional feedback between the reservoir characterization team and the reservoir engineering/simulation team to allow simultaneous refinement and convergence of the geological interpretation with the reservoir model. The fundamental conclusion from the study is that South Cowden exhibits favorable enhanced oil recovery characteristics, particularly reservoir quality and continuity.

Hallenbeck, L.D.; Harpole, K.J.; Gerard, M.G.

1996-05-01T23:59:59.000Z

314

Advances in Drilling Technology -E-proceedings of the First International Conference on Drilling Technology (ICDT -2010) and National Workshop on Manpower Development in Petroleum Engineering (NWMDPE -2010), November 18-21, 2010.  

E-Print Network (OSTI)

of Technology Madras, Chennai (TN) - 600 036, India. Transfer of experience for improved oil well drilling PÃ¥l The drilling process is getting increasingly more complex as oil fields mature and technology evolves actions. KEYWORDS: Oil well drilling, experience transfer, ontology, drilling failure, downtime, case

Aamodt, Agnar

315

Fort Bliss exploratory slimholes: Drilling and testing  

SciTech Connect

During November/96 to April/97 Sandia National Laboratories provided consulation, data collection, analysis and project documentation to the U.S. Army for a series of four geothermal exploratory slimholes drilled on the McGregor Range approximately 25 miles north of El Paso, Texas. This drilling was directed toward evaluating a potential reservoir for geothermal power generation in this area, with a secondary objective of assessing the potential for direct use applications such as space heating or water de-salinization. This report includes: representative temperature logs from the wells; daily drilling reports; a narrative account of the drilling and testing; a description of equipment used; a summary and preliminary interpretation of the data; and recommendations for future work.

Finger, J.T.; Jacobson, R.D.

1997-12-01T23:59:59.000Z

316

Blast furnace taphole drill  

SciTech Connect

A blast furnace taphole drill has a flaring head with cutting edges at its cutting end formed by intersecting angled faces. A central bore carries cleaning air to the cutting end. To prevent blockage of the cleaning air bore by debris and possible jamming of the drill, the head has deep radial grooves formed at the bottoms of the valley shapes between the cutting edges. The grooves extend radially from the air bore and conduct the air so that it can get behind or under jammed debris. Reduced taphole drilling times can be achieved.

Gozeling, J.A.; de Boer, S.; Spiering, A.A.

1984-06-26T23:59:59.000Z

317

Economic analysis of shale gas wells in the United States  

E-Print Network (OSTI)

Natural gas produced from shale formations has increased dramatically in the past decade and has altered the oil and gas industry greatly. The use of horizontal drilling and hydraulic fracturing has enabled the production ...

Hammond, Christopher D. (Christopher Daniel)

2013-01-01T23:59:59.000Z

318

Evaluation of potential kick scenarios in riserless drilling  

E-Print Network (OSTI)

when drilling conventionally is somewhat different from the procedures when drilling riserless. The two most common methods of kick killing utilized in conventional drilling, are the "Driller's Method" and the "Wait and Weight Method" (also referred... to as the "Engineers Method" )' . The basic procedure utilized by the Driller's Method is to shut in the well, measure stabilized shut-in drillpipe pressure (SIDPP), shut-in casing pressure (SICP), and pit gain. Circulate the kick up the annulus and out...

Seland, Stig

1999-01-01T23:59:59.000Z

319

Effect of non-aqueous drilling fluid and its synthetic base oil on soil health as indicated by its dehydrogenase activity  

Science Journals Connector (OSTI)

Drilling fluids are used for drilling natural gas, oil and water wells. These spill over into the surrounding soil at the point of drilling, which may impair soil health. A ... out to determine the effect of non ...

Kanchan Wakadikar; Avik Sil; Niranjan Kolekar…

2011-09-01T23:59:59.000Z

320

Observation Wells | Open Energy Information  

Open Energy Info (EERE)

Observation Wells Observation Wells Jump to: navigation, search GEOTHERMAL ENERGYGeothermal Home Exploration Technique: Observation Wells Details Activities (7) Areas (7) Regions (0) NEPA(15) Exploration Technique Information Exploration Group: Drilling Techniques Exploration Sub Group: Development Drilling Parent Exploration Technique: Development Drilling Information Provided by Technique Lithology: Stratigraphic/Structural: Hydrological: Total dissolved solids, fluid pressure, flow rates, and flow direction Thermal: Monitors temperature of circulating fluids Dictionary.png Observation Wells: An observation well is used to monitor important hydrologic parameters in a geothermal system that can indicate performance, longevity, and transient processes. Other definitions:Wikipedia Reegle

Note: This page contains sample records for the topic "horizontal wells drilling" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


321

The Removal of Crude Oil in Waste Drilling Muds by a Constructed Microbial Consortium  

Science Journals Connector (OSTI)

Waste drilling muds (WDMs) contain serious pollutants produced by crude oil and gas well drilling. Bioremediation has been known as a useful ... enrichment of indigenous microorganisms, which can remove oil conta...

Yunkang Chang; Xingbiao Wang; Yifan Han…

2014-01-01T23:59:59.000Z

322

GEOPHYSICAL WELL LOG/CORE DESCRIPTIONS, CHEROKEE AND BUG FIELDS, SAN JUAN COUNTY, UTAH, AND LITTLE UTE AND SLEEPING UTE FIELDS, MONTEZUMA COUNTY, COLORADO  

SciTech Connect

Over 400 million barrels (64 million m{sup 3}) of oil have been produced from the shallow-shelf carbonate reservoirs in the Pennsylvanian (Desmoinesian) Paradox Formation in the Paradox Basin, Utah and Colorado. With the exception of the giant Greater Aneth field, the other 100 plus oil fields in the basin typically contain 2 to 10 million barrels (0.3-1.6 million m{sup 3}) of original oil in place. Most of these fields are characterized by high initial production rates followed by a very short productive life (primary), and hence premature abandonment. Only 15 to 25 percent of the original oil in place is recoverable during primary production from conventional vertical wells. An extensive and successful horizontal drilling program has been conducted in the giant Greater Aneth field. However, to date, only two horizontal wells have been drilled in small Ismay and Desert Creek fields. The results from these wells were disappointing due to poor understanding of the carbonate facies and diagenetic fabrics that create reservoir heterogeneity. These small fields, and similar fields in the basin, are at high risk of premature abandonment. At least 200 million barrels (31.8 million m{sup 3}) of oil will be left behind in these small fields because current development practices leave compartments of the heterogeneous reservoirs undrained. Through proper geological evaluation of the reservoirs, production may be increased by 20 to 50 percent through the drilling of low-cost single or multilateral horizontal legs from existing vertical development wells. In addition, horizontal drilling from existing wells minimizes surface disturbances and costs for field development, particularly in the environmentally sensitive areas of southeastern Utah and southwestern Colorado.

Thomas C. Chidsey Jr; David E. Eby; Laura L. Wray

2003-12-01T23:59:59.000Z

323

Advanced Seismic While Drilling System  

SciTech Connect

A breakthrough has been discovered for controlling seismic sources to generate selectable low frequencies. Conventional seismic sources, including sparkers, rotary mechanical, hydraulic, air guns, and explosives, by their very nature produce high-frequencies. This is counter to the need for long signal transmission through rock. The patent pending SeismicPULSER{trademark} methodology has been developed for controlling otherwise high-frequency seismic sources to generate selectable low-frequency peak spectra applicable to many seismic applications. Specifically, we have demonstrated the application of a low-frequency sparker source which can be incorporated into a drill bit for Drill Bit Seismic While Drilling (SWD). To create the methodology of a controllable low-frequency sparker seismic source, it was necessary to learn how to maximize sparker efficiencies to couple to, and transmit through, rock with the study of sparker designs and mechanisms for (a) coupling the sparker-generated gas bubble expansion and contraction to the rock, (b) the effects of fluid properties and dynamics, (c) linear and non-linear acoustics, and (d) imparted force directionality. After extensive seismic modeling, the design of high-efficiency sparkers, laboratory high frequency sparker testing, and field tests were performed at the University of Texas Devine seismic test site. The conclusion of the field test was that extremely high power levels would be required to have the range required for deep, 15,000+ ft, high-temperature, high-pressure (HTHP) wells. Thereafter, more modeling and laboratory testing led to the discovery of a method to control a sparker that could generate low frequencies required for deep wells. The low frequency sparker was successfully tested at the Department of Energy Rocky Mountain Oilfield Test Center (DOE RMOTC) field test site in Casper, Wyoming. An 8-in diameter by 26-ft long SeismicPULSER{trademark} drill string tool was designed and manufactured by TII. An APS Turbine Alternator powered the SeismicPULSER{trademark} to produce two Hz frequency peak signals repeated every 20 seconds. Since the ION Geophysical, Inc. (ION) seismic survey surface recording system was designed to detect a minimum downhole signal of three Hz, successful performance was confirmed with a 5.3 Hz recording with the pumps running. The two Hz signal generated by the sparker was modulated with the 3.3 Hz signal produced by the mud pumps to create an intense 5.3 Hz peak frequency signal. The low frequency sparker source is ultimately capable of generating selectable peak frequencies of 1 to 40 Hz with high-frequency spectra content to 10 kHz. The lower frequencies and, perhaps, low-frequency sweeps, are needed to achieve sufficient range and resolution for realtime imaging in deep (15,000 ft+), high-temperature (150 C) wells for (a) geosteering, (b) accurate seismic hole depth, (c) accurate pore pressure determinations ahead of the bit, (d) near wellbore diagnostics with a downhole receiver and wired drill pipe, and (e) reservoir model verification. Furthermore, the pressure of the sparker bubble will disintegrate rock resulting in an increased overall rates of penetration. Other applications for the SeismicPULSER{trademark} technology are to deploy a low-frequency source for greater range on a wireline for Reverse Vertical Seismic Profiling (RVSP) and Cross-Well Tomography. Commercialization of the technology is being undertaken by first contacting stakeholders to define the value proposition for rig site services utilizing SeismicPULSER{trademark} technologies. Stakeholders include national oil companies, independent oil companies, independents, service companies, and commercial investors. Service companies will introduce a new Drill Bit SWD service for deep HTHP wells. Collaboration will be encouraged between stakeholders in the form of joint industry projects to develop prototype tools and initial field trials. No barriers have been identified for developing, utilizing, and exploiting the low-frequency SeismicPULSER{trademark} source in a

Robert Radtke; John Fontenot; David Glowka; Robert Stokes; Jeffery Sutherland; Ron Evans; Jim Musser

2008-06-30T23:59:59.000Z

324

Snubdrilling a new well in Venezuela  

SciTech Connect

A new well was successfully drilled using a snubbing jack. The drill bit was rotated using a rotary table, downhole motors and combination of the two. Expected high-pressure zones prompted this use of ``snubdrilling.`` The primary objective was to drill a vertical well through underlying sands and gain information about formation pressures. This data would aid in the drilling of a relief well using a conventional drilling rig. The secondary objective was to relieve pressure by putting this new well on production. In addition to special high-pressure drilling jobs, there are other drilling applications where snubbing jacks are a feasible alternative to conventional rotary drilling rigs or coiled tubing units. Slimhole, underbalanced and flow drilling, and sidetracking of existing wells are excellent applications for snubdrilling. Advantages of snubdrilling vs. coiled tubing drilling, include ability to rotate drillstrings, use high-torque downhole motors, pump at high rates and pressures, apply significant overpull in case of stuck pipe, and run casing and liners without rigging down. Shortcomings of drilling with snubbing jacks compared to coiled tubing are the need to stop circulation while making new connections and inability to run continuous cable inside workstrings.

Aasen, J.

1995-12-01T23:59:59.000Z

325

RAPID/Geothermal/Well Field/Hawaii | Open Energy Information  

Open Energy Info (EERE)

& Well Field Permit A developer seeking to drill, modify, or modify the use of a well for exploration or development must receive a drilling or modification permit prior to...

326

EIA Drilling Productivity Report  

U.S. Energy Information Administration (EIA) Indexed Site

Drilling Productivity Report Drilling Productivity Report For Center on Global Energy Policy, Columbia University October 29, 2013 | New York, NY By Adam Sieminski, Administrator The U.S. has experienced a rapid increase in natural gas and oil production from shale and other tight resources Adam Sieminski, EIA Drilling Productivity Report October 29, 2013 2 0 5 10 15 20 25 30 35 2000 2002 2004 2006 2008 2010 2012 Rest of US Marcellus (PA and WV) Haynesville (LA and TX) Eagle Ford (TX) Bakken (ND) Woodford (OK) Fayetteville (AR) Barnett (TX) Antrim (MI, IN, and OH) 0.0 0.4 0.8 1.2 1.6 2.0 2.4 2.8 2000 2002 2004 2006 2008 2010 2012 Eagle Ford (TX) Bakken (MT & ND) Granite Wash (OK & TX) Bonespring (TX Permian) Wolfcamp (TX Permian) Spraberry (TX Permian) Niobrara-Codell (CO) Woodford (OK)

327

Marcellus Shale Drilling and Hydraulic Fracturing; Technicalities and  

E-Print Network (OSTI)

Pipe · Air Rotary Drilling Rig · Hydraulic Rotary Drilling Rig ­ Barite/Bentonite infused drilling muds A "Thumper Truck" #12;Rigging Up #12;Drilling · The Drill String ­ Diesel Powered ­ Drilling Bit ­ Drilling

Jiang, Huiqiang

328

Deep-water drilling remains a risky business  

Science Journals Connector (OSTI)

... Two years after the blowout of the BP oil well drilled by the Deepwater Horizon rig in the Gulf of Mexico, the United States is largely failing to act on ... commission that produced the report Deep Water: The Gulf Oil Disaster and the Future of Offshore Drilling — the other was Cherry Murray of Harvard University. The commission concluded that ...

Donald Boesch

2012-04-17T23:59:59.000Z

329

US deep geothermal drilling for 1973-1980  

SciTech Connect

The number of deep geothermal wells drilled in 1973 through 1980 are analyzed. The rate of drilling was constant from 1973 through 1978, but appears to have increased starting in 1979. The increase has occurred mainly at The Geysers and at exploratory locations outside of California.

Gerstein, R.E.; Entingh, D.J.

1981-10-01T23:59:59.000Z

330

Economic analysis of waterflood infill drilling in Texas  

E-Print Network (OSTI)

IN MID 1980 DOLLARS 3 COST ESCALATION FACTORS FOR INFILL WELL COSTS 4 ANNUAL OPERATING COSTS AND INDEXES FOR WEST TEXAS SECONDARY RECOVERY PROJECTS WITH 10 PRODUCERS AND 11 INJECTION WELLS 5 HISTORICAL AVERAGE OIL AND GAS PRICES 6 INFILL DRILLING... IN MID 1980 DOLLARS 3 COST ESCALATION FACTORS FOR INFILL WELL COSTS 4 ANNUAL OPERATING COSTS AND INDEXES FOR WEST TEXAS SECONDARY RECOVERY PROJECTS WITH 10 PRODUCERS AND 11 INJECTION WELLS 5 HISTORICAL AVERAGE OIL AND GAS PRICES 6 INFILL DRILLING...

Reviere, Randall Hooge

2012-06-07T23:59:59.000Z

331

Horizontal Plate Plate  

NLE Websites -- All DOE Office Websites (Extended Search)

Horizontal Plate Plate Horizontal Plate Plate Metadata also available as Metadata: Identification_Information Data_Quality_Information Spatial_Data_Organization_Information Spatial_Reference_Information Entity_and_Attribute_Information Distribution_Information Metadata_Reference_Information Identification_Information: Citation: Citation_Information: Originator: Ray George Publication_Date: Unknown Title: Horizontal Plate Plate Geospatial_Data_Presentation_Form: vector digital data Online_Linkage: Description: Abstract: Monthly and annual average solar resource potential for the lower 48 states Purpose: Provide information on the solar resource potential for the lower 48

332

Naming chemical compounds: Calculator drill  

Science Journals Connector (OSTI)

36. Bits and pieces, 13. A calculator can be programmed to drill students on chemical compound naming rules.

David Holdsworth; Evelyn Lacanienta

1983-01-01T23:59:59.000Z

333

ARM - Measurement - Horizontal wind  

NLE Websites -- All DOE Office Websites (Extended Search)

govMeasurementsHorizontal wind govMeasurementsHorizontal wind ARM Data Discovery Browse Data Comments? We would love to hear from you! Send us a note below or call us at 1-888-ARM-DATA. Send Measurement : Horizontal wind The horizontal wind in terms of either speed and direction, or the zonal (u) and meridional (v) components. Categories Atmospheric State Instruments The above measurement is considered scientifically relevant for the following instruments. Refer to the datastream (netcdf) file headers of each instrument for a list of all available measurements, including those recorded for diagnostic or quality assurance purposes. ARM Instruments SONDE : Balloon-Borne Sounding System CO2FLX : Carbon Dioxide Flux Measurement Systems ECOR : Eddy Correlation Flux Measurement System DISDROMETER : Impact Disdrometer

334

Calculator program optimizes bit weight, rotary speed, reducing drilling cost  

SciTech Connect

Bit selection, bit weight, and rotary speed have repeatedly proven to be the most important and commonly overlooked alterable factors which control penetration rate, footage, and overall drilling cost. This is particularly true in offshore operations where drilling costs are highest and the greatest cost savings stand to be achieved through implementation of proven optimization techniques. The myth that bit weights and rotary speeds cannot be optimized in directional holes has hindered the industry from using this virtually cost-free method for reducing drilling cost. The use of optimized bit weights and rotary speeds in conjunction with minimum cost bit programs based on cost per foot analysis of previous bit runs in the area was implemented on a five-well platform in the Grand Isle Block 20 field, offshore Louisiana. Each of the directional wells was drilled substantially faster and cheaper than the discovery well, which was a straight hole. Average reductions in footage cost of 31.3%, based on daily operating cost of $30,000/day, and increase in average daily footage drilled of 45.2% were effected by ''collectively optimizing'' drilling performance. The ''Optimizer'' program is an HP-41CV adaptation of the Bourgoyne and Young drilling model. It was used to calculate the optimum bit weights and rotary speeds based on field drilling tests; historical bit and bearing wear data; and current operating conditions, cost, and constraints.

Simpson, M.A.

1984-04-23T23:59:59.000Z

335

ECONOMIC RECOVERY OF OIL TRAPPED AT FAN MARGINS USING HIGH ANGLE WELLS AND MULTIPLE HYDRAULIC FRACTURES  

SciTech Connect

This project attempts to demonstrate the effectiveness of exploiting thin-layered, low-energy deposits at the distal margin of a prograding turbidite complex through the use of hydraulically fractured horizontal or high-angle wells. The combination of a horizontal or high-angle well and hydraulic fracturing will allow greater pay exposure than can be achieved with conventional vertical wells while maintaining vertical communication between thin interbedded layers and the wellbore. A high-angle well will be drilled in the fan-margin portion of a slope-basin clastic reservoir and will be completed with multiple hydraulic-fracture treatments. Geologic modeling, reservoir characterization, and fine-grid reservoir simulation will be used to select the well location and orientation. Design parameters for the hydraulic-fracture treatments will be determined, in part, by fracturing an existing test well. Fracture azimuth will be predicted by passive seismic monitoring of a fracture-stimulation treatment in the test well using logging tools in an offset well. The long radius, near horizontal well was drilled during the first quarter of 1996. Well conditions resulted in the 7 in. production liner sticking approximately 900 ft off bottom. Therefore, a 5 in. production liner was necessary to case this portion of the target formation. Swept-out sand intervals and a poor cement bond behind the 5 in. liner precluded two of the three originally planned hydraulic fracture treatments. As a result, all pay intervals behind the 5 in. liner were perforated and stimulated with a non-acid reactive fluid. Following a short production period, the remaining pay intervals in the well (behind the 7 in. liner) were perforated. The well was returned to production to observe production trends and pressure behavior and assess the need to stimulate the new perforations.

Mike L. Laue

2001-09-28T23:59:59.000Z

336

invert(ed) (oil) emulsion (drilling) mud  

Science Journals Connector (OSTI)

invert(ed) (oil) emulsion (drilling) mud, water-in-oil (drilling) mud ? Wasser-in-Öl-(Bohr)...m, (f)

2014-08-01T23:59:59.000Z

337

water-in-oil (drilling) mud  

Science Journals Connector (OSTI)

water-in-oil (drilling) mud, invert(ed) (oil) emulsion (drilling) mud ? Wasser-in-Öl-(Bohr)...m, (f)

2014-08-01T23:59:59.000Z

338

Dual, rotating stripper rubber drilling head  

SciTech Connect

In a drilling head for a well bore through which a tool string of varying outside diameter is run, the drilling head sealing against fluid flow past the tool string to divert such fluid through a side outlet port, said drilling head including a housing having an axial passageway through which the tool string is run and a bearing assembly to facilitate rotation of the tool string within the axial passageway, the improved drilling head comprising: first and second stripper rubbers rotatably mounted within the drilling head housing in seating contact with the tool string, said stripper rubbers having substantially identical inner diameters through which the tool string extends, said first stripper rubber formed of an abrasive resistant material to divert fluid flow from the axial passageway of the housing to the side outlet port and said second stripper rubber formed on a sealingly resilient material which maintains sealing contact with the tool string extending there through preventing fluid flow past said tool string; said first stripper rubber being corrected to clamping means associated with the bearing assembly through a first drive ring such that said first stripper rubber rotates with the tool string; and said second stripper rubber is rotatably connected to said clamping means associated with the bearing assembly through a second drive ring, said first and second drive rings coaxially mounted within the housing whereby said first stripper rubber is positioned axially below said second stripper rubber in sealing contact with the tool string.

Bailey, T.F.; Campbell, J.E.

1993-05-25T23:59:59.000Z

339

Drilling Waste Management Fact Sheet: Offsite Disposal at Commercial  

NLE Websites -- All DOE Office Websites (Extended Search)

Commercial Disposal Facilities Commercial Disposal Facilities Fact Sheet - Commercial Disposal Facilities Although drilling wastes from many onshore wells are managed at the well site, some wastes cannot be managed onsite. Likewise, some types of offshore drilling wastes cannot be discharged, so they are either injected underground at the platform (not yet common in the United States) or are hauled back to shore for disposal. According to an American Petroleum Institute waste survey, the exploration and production segment of the U.S. oil and gas industry generated more than 360 million barrels (bbl) of drilling wastes in 1985. The report estimates that 28% of drilling wastes are sent to offsite commercial facilities for disposal (Wakim 1987). A similar American Petroleum Institute study conducted ten years later found that the volume of drilling waste had declined substantially to about 150 million bbl.

340

Precision micro drilling with copper vapor lasers  

SciTech Connect

The authors have developed a copper vapor laser based micro machining system using advanced beam quality control and precision wavefront tilting technologies. Micro drilling has been demonstrated through percussion drilling and trepanning using this system. With a 30 W copper vapor laser running at multi-kHz pulse repetition frequency, straight parallel holes with size varying from 500 microns to less than 25 microns and with aspect ratio up to 1:40 have been consistently drilled on a variety of metals with good quality. For precision trepanned holes, the hole-to-hole size variation is typically within 1% of its diameter. Hole entrance and exit are both well defined with dimension error less than a few microns. Materialography of sectioned holes shows little (sub-micron scale) recast layer and heat affected zone with surface roughness within 1--2 microns.

Chang, J.J.; Martinez, M.W.; Warner, B.E.; Dragon, E.P.; Huete, G.; Solarski, M.E.

1994-09-02T23:59:59.000Z

Note: This page contains sample records for the topic "horizontal wells drilling" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


341

Nonplanar fracture propagation from a horizontal wellbore: Experimental study  

SciTech Connect

This paper presents experimental results related to hydraulic fracturing of a horizontal well, specifically the nonplanar fracture geometries resulting from fracture initiation and propagation. Experiments were designed to investigate nonplanar fracture geometries. This paper discusses how these nonplanar fractures can be responsible for premature screenout and excessive treatment pressure when a horizontal well is hydraulically fractured. Reasons for unsuccessful hydraulic fracturing treatments of a horizontal well are presented and recommendations to ensure clear communication channels between the wellbore and the fracture are given.

Abass, H.H.; Hedayati, S.; Meadows, D.L.

1996-08-01T23:59:59.000Z

342

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

SciTech Connect

Implementation of the work program of Budget Period 2 of the East Binger Unit (''EBU'') DOE Project is complete. Two additional vertical infill wells were drilled, completed, and brought on production during the reporting period. These were the last two of five wells to be drilled in the pilot area. Additional drilling is planned for Budget Period 3. Overall response to the various projects continues to be very favorable. Nitrogen injection into the pilot area had doubled prior to unrelated nitrogen supply problems, while gas production and nitrogen content of produced gas have both decreased. Nitrogen recycle within the pilot area has dropped from 60% to 20%. Meanwhile, pilot area oil production has increased from 300 bpd prior to development to an average of 435 bpd for January through March 2004. March production was the highest at 542 bpd due to the addition of the two new vertical wells. Production performances of the new wells continue to support the current opinion that horizontal wells do not provide sufficient additional production over vertical wells to justify their incremental cost.

Joe Sinner

2004-06-03T23:59:59.000Z

343

Calculating limits for torsion and tensile loads on drill pipe  

SciTech Connect

Drill pipe used for drilling horizontal and extended reach holes experiences much higher torsional and tensile loads than normally seen while drilling vertical holes. This is particularly true for rigs with top drives vs. rigs with rotary tables. When pipe is rotated while pulling out of the hole, which is commonly done on top drive rigs, the drill pipe can experience high tensile and torsional loading simultaneously. These conditions increase the probability of overload on tool joints and require that the drill pipe and tool joint selection process include consideration of combined loading. Calculating the required drill pipe strength for vertical holes is straightforward and spelled out in Section 5 of API RP7G. In vertical hole applications, pipe is almost always selected for its tensile capacity and the torsional strength of the pipe generally does not require special consideration. In Section 4 of API Sec 7, API recommends that the tool joints have a torsional strength of 80% of the pipe`s torsional strength; this is usually adequate. The torsional strength and tensile strength of commonly used drill pipe and tool joint combinations are tabulated in Tables 2 through 10 of API RP7G. Appendix A.8.3 in API RP7G shows a method for plotting a graphical representation of the combined torsional and tensile operational limits of tool joints. How to calculate the limits of the drill pipe tube is shown in Appendix A.9.2. This paper defines terms and limits, and discusses building and using a diagram to determine safe loads.

Bailey, E.I. [Stress Engineering Service Inc., Houston, TX (United States); Smith, J.E. [Grant Prideco, Houston, TX (United States)

1998-02-01T23:59:59.000Z

344

Drilling subsurface wellbores with cutting structures  

DOE Patents (OSTI)

A system for forming a wellbore includes a drill tubular. A drill bit is coupled to the drill tubular. One or more cutting structures are coupled to the drill tubular above the drill bit. The cutting structures remove at least a portion of formation that extends into the wellbore formed by the drill bit.

Mansure, Arthur James (Alburquerque, NM); Guimerans, Rosalvina Ramona (The Woodlands, TX)

2010-11-30T23:59:59.000Z

345

Exploration Drilling | Open Energy Information  

Open Energy Info (EERE)

Exploration Drilling Exploration Drilling Jump to: navigation, search GEOTHERMAL ENERGYGeothermal Home Exploration Technique: Exploration Drilling Details Activities (0) Areas (0) Regions (0) NEPA(15) Exploration Technique Information Exploration Group: Drilling Techniques Exploration Sub Group: Exploration Drilling‎ Parent Exploration Technique: Drilling Techniques Information Provided by Technique Lithology: Identify lithology and mineralization, provide core samples and rock cuttings Stratigraphic/Structural: Retrieved samples can be used to identify stratigraphy and structural features such as fracture networks or faults Hydrological: -Water samples can be used for geochemical analysis -Fluid pressures can be used to estimate flow rates Thermal: -Temperatures can be measured within the hole

346

Development Drilling | Open Energy Information  

Open Energy Info (EERE)

Page Page Edit with form History Facebook icon Twitter icon » Development Drilling Jump to: navigation, search GEOTHERMAL ENERGYGeothermal Home Exploration Technique: Development Drilling Details Activities (1) Areas (1) Regions (0) NEPA(9) Exploration Technique Information Exploration Group: Drilling Techniques Exploration Sub Group: Development Drilling Parent Exploration Technique: Drilling Techniques Information Provided by Technique Lithology: Identify lithology and mineralization, provide core samples and rock cuttings Stratigraphic/Structural: Retrieved samples can be used to identify stratigraphy and structural features such as fracture networks or faults Hydrological: -Water samples can be used for geochemical analysis -Fluid pressures can be used to estimate flow rates

347

Cost effectiveness of sonic drilling  

SciTech Connect

Sonic drilling (combination of mechanical vibrations and rotary power) is an innovative environmental technology being developed in cooperation with DOE`s Arid-Site Volatile Organic Compounds Integrated Demonstration at Hanford and the Mixed Waste Landfill Integrated Demonstration at Sandia. This report studies the cost effectiveness of sonic drilling compared with cable-tool and mud rotary drilling. Benefit of sonic drilling is its ability to drill in all types of formations without introducing a circulating medium, thus producing little secondary waste at hazardous sites. Progress has been made in addressing the early problems of failures and downtime.

Masten, D.; Booth, S.R.

1996-03-01T23:59:59.000Z

348

Geothermal drilling and completion technology development program. Quarterly progress report, April-June 1980  

SciTech Connect

The progress, status, and results of ongoing research and development (R and D) within the Geothermal Drilling and Completion Technology Development Program are reported. The program emphasizes the development of geothermal drilling hardware, drilling fluids, completion technology, and lost circulation control methods. Advanced drilling systems are also under development. The goals of the program are to develop the technology required to reduce well costs by 25% by 1983 and by 50% by 1987.

Varnado, S.G.

1980-07-01T23:59:59.000Z

349

Geothermal drilling and completion technology development program. Quarterly progress report, October-December 1979  

SciTech Connect

The progress, status, and results of ongoing Research and Development (R and D) within the Geothermal Drilling and Completion Technology Development Program are described. The program emphasizes the development of geothermal drilling hardware, drilling fluids, and completion technology. Advanced drilling systems are also under development. The goals of the program are to develop the technology required to reduce well costs by 25% by 1982 and by 50% by 1986.

Varnado, S.G. (ed.)

1980-01-01T23:59:59.000Z

350

Test instructions for the horizontal borehole demonstration at the Near-Surface Test Facility  

SciTech Connect

This test outlines the planned activities designed to demonstrate the horizontal borehole drilling and testing operations at the Near Surface Test Facility prior to the performance of these methods within the Exploratory Shaft underground facility. This document will also lead to establishing the operating and safety procedures which will be implemented in the Exploratory Shaft long exploratory borehole drilling and testing program. 7 refs., 3 figs., 1 tab.

McLellan, G.W. (Rockwell International Corp., Richland, WA (USA). Energy Systems Group)

1984-03-01T23:59:59.000Z

351

Slimhole Drilling, Logging, and Completion Technology - An Update  

SciTech Connect

Using slim holes (diameter < 15 cm) for geothermal exploration and small-scale power production can produce significant cost savings compared to conventional rotary-drilling methods. In addition, data obtained from slim holes can be used to lower the risks and costs associated with the drilling and completion of large-diameter geothermal wells. As a prime contractor to the U.S. Department of Energy (DOE), Sandia National Laboratories has worked with industry since 1992 to develop and promote drilling, testing, and logging technology for slim holes. This paper describes the current status of work done both in-house and contracted to industry. It focuses on drilling technology, case histories of slimhole drilling projects, data collection and rig instrumentation, and high-temperature logging tools.

FINGER,JOHN T.; JACOBSON,RONALD D.

1999-10-07T23:59:59.000Z

352

DOE Lab Receives Award for Work on Drilling Technology | Department of  

Energy.gov (U.S. Department of Energy (DOE)) Indexed Site

DOE Lab Receives Award for Work on Drilling Technology DOE Lab Receives Award for Work on Drilling Technology DOE Lab Receives Award for Work on Drilling Technology June 13, 2013 - 11:52am Addthis DOE Lab Receives Award for Work on Drilling Technology Directional drilling - the drilling of non-vertical wells that helped make the development of shale gas possible -- will continue to play a key role in energy development, and so will the technologies that make it possible. The benefits of directional drilling are tremendous. Think cleaner, cheaper electricity; local economy booms; and decreased dependence on foreign energy. The unconventional oil and gas resources that can be tapped through directional drilling benefit consumers, businesses, and even the transportation sector. So being recognized as an innovator in this area is

353

Big-hole drilling - the state of the art  

SciTech Connect

The art of big-hole drilling has been in a continual state of evolution at the Nevada Test Site since the start of underground testing in 1961. Emplacement holes for nuclear devices are still being drilled by the rotary-drilling process, but almost all the hardware and systems have undergone many changes during the intervening years. The current design of bits, cutters, and other big-hole-drilling hardware results from contributions of manufacturers and Test Site personnel. The dual-string, air-lift, reverse-circulation system was developed at the Test Site. Necessity was really the Mother of this invention, but this circulation system is worthy of consideration under almost any condition. Drill rigs for big-hole drilling are usually adaptations of large oil-well drill rigs with minor modifications required to handle the big bits and drilling assemblies. Steel remains the favorite shaft lining material, but a lot of thought is being given to concrete linings, especially precast concrete.

Lackey, M.D.

1983-01-01T23:59:59.000Z

354

Use of Clays as Drilling Fluids and Filters  

Science Journals Connector (OSTI)

In geotechnical engineering, drilling fluid is a fluid used to drill boreholes into the earth. In drilling rigs, drilling fluids help to do drill for exploration of oil and natural gas. Liquid drilling fluid is o...

Swapna Mukherjee

2013-01-01T23:59:59.000Z

355

Geothermal Drilling Success at Blue Mountain, Nevada | Open Energy  

Open Energy Info (EERE)

Drilling Success at Blue Mountain, Nevada Drilling Success at Blue Mountain, Nevada Jump to: navigation, search OpenEI Reference LibraryAdd to library Conference Paper: Geothermal Drilling Success at Blue Mountain, Nevada Abstract Exploration in a blind prospect has led to the confirmation of a geothermal resource at Blue Mt.Nevada. The latest results include drilling of three production wells into Piedmont faults. These wells produce from a 185 to 190°C dilute benign brine reservoir. Short flow tests have shown prolific flow rates and indications of reservoir continuity.Well entries have shown that system permeability is fault-dominated. This is confirmed by the results of seismic reflection imaging. Young faulting in the area includes intersecting range front faults that strike NW, NS, and NE. Exposure of

356

Step-out Well | Open Energy Information  

Open Energy Info (EERE)

Step-out Well Step-out Well Jump to: navigation, search GEOTHERMAL ENERGYGeothermal Home Exploration Technique: Step-out Well Details Activities (5) Areas (5) Regions (0) NEPA(0) Exploration Technique Information Exploration Group: Drilling Techniques Exploration Sub Group: Exploration Drilling Parent Exploration Technique: Exploration Drilling Information Provided by Technique Lithology: Drill cuttings are analyzed to determine lithology and mineralogy Stratigraphic/Structural: Fractures, faults, and geologic formations that the well passes through are identified and mapped Hydrological: Identify aquifers, reservoir boundaries, flow rates, fluid pressure, and chemistry Thermal: Direct temperature measurements from within the reservoir Dictionary.png Step-out Well: A well drilled outside of the proven reservoir boundaries to investigate a

357

Recent Developments in Geothermal Drilling Fluids  

SciTech Connect

In the past, standard drilling muds have been used to drill most geothermal wells. However, the harsh thermal and chemical environment and the unique geothermal formations have led to such problems as excessive thickening of the fluid, formation damage, and lost circulation. This paper describes three recent development efforts aimed at solving some of these drilling fluid problems. Each of the efforts is at a different stage of development. The Sandia aqueous foam studies are still in the laboratory phase, NL Baroid's polymeric deflocculant is soon to be field tested, and the Mudtech high-temperature mud was field tested several months ago. Low density and the capability to suspend particles at low relative velocities are two factors which make foam an attractive drilling fluid. The stability of these foams and their material properties at high temperatures are presently unknown and this lack of information has precluded their use as a geothermal drilling fluid. The aqueous foam studies being conducted at Sandia are aimed at screening available surfactants for temperature and chemical stability. Approximately 100 surfactants have been tested at temperatures of 260 and 310 C (500 and 590 F), and several of these candidates appear very promising. NL Baroid has developed a polymeric deflocculant for water-based muds which shows promise in retarding thermal degradation effects and associated gelation. Formulations containing this new polymer have shown good rheological properties up to 260 C (500 F) in laboratory testing. A high-temperature mud consisting primarily of sepiolite, bentonite, and brown coal has been developed by Mudtech, Inc. A field test of this mud was conducted in a geothermal well in the Imperial Valley of California in May 1980. The fluid exhibited good hole-cleaning characteristics and good rheological properties throughout the test.

Kelsey, J. R.; Rand, P. B.; Nevins, M. J.; Clements, W. R.; Hilscher, L. W.; Remont, L. J.; Matula, G. W.; Balley, D. N.

1981-01-01T23:59:59.000Z

358

W. Canada boom to outshine second half U. S. drilling rise  

SciTech Connect

Drilling in the US will pick up slightly during second half 1994, but the first half to second half increase proportionally will not be as large as in Canada. Operators appear likely to drill nearly half as many wells this year in western Canada as they will drill in the US. Oil and Gas Journal estimates that drilling and completion spending will total $9.511 billion in the US this year, up about one third of 1% from spending in 1993. This steady investment is forecast despite a 2.3% drop in expected wellhead revenue to $72.53 billion. Highlights to OGJ's midyear drilling forecast for 1994 include: operators will drill 24,705 wells, compared with the 26,840 OGJ estimated in its early year forecast before the slump in crude oil prices; the active rotary rig count will average 810 rigs, 7% higher than in 1993; operators will drill about 3,684 wildcats, down from the 4,170 that OGJ predicted in January; the surveyed group of major operators will drill 3,091 wells in the US, including 246 exploratory wells; and drilling in western Canada will total a year record 11,531 wells, dwarfing the 4,654 wells drilled in 1992.

Petzet, G.A.; Beck, R.J.

1994-07-25T23:59:59.000Z

359

Drilling Systems | Open Energy Information  

Open Energy Info (EERE)

source source History View New Pages Recent Changes All Special Pages Semantic Search/Querying Get Involved Help Apps Datasets Community Login | Sign Up Search Page Edit History Facebook icon Twitter icon » Drilling Systems Jump to: navigation, search Contents 1 Geothermal Lab Call Projects for Drilling Systems 2 Geothermal ARRA Funded Projects for Drilling Systems Geothermal Lab Call Projects for Drilling Systems Loading map... {"format":"googlemaps3","type":"ROADMAP","types":["ROADMAP","SATELLITE","HYBRID","TERRAIN"],"limit":200,"offset":0,"link":"all","sort":[""],"order":[],"headers":"show","mainlabel":"","intro":"","outro":"","searchlabel":"\u2026

360

Drill Program Ensures Emergency Preparedness  

NLE Websites -- All DOE Office Websites (Extended Search)

underground event. Drill scenarios have included a full evacuation of the WIPP underground facility and responding to radiological incidents and a variety of emergencies on the...

Note: This page contains sample records for the topic "horizontal wells drilling" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


361

Drill-bit with full offset cutter bodies  

SciTech Connect

A rotary drag drill bit is seen wherein cutter bodies are rotatively connected to a main body structure at a fully offset position. The fully offset position is defined by a rotational axis of each cutter body, a longitudinal axis of the drill bit and end support points or positions of the cutter bodies. The rotational axes of the cutter bodies are perpendicular to the longitudinal axis of the drill bit. The end supports of the cutter body are each equal distance from any point on the longitudinal axis of the drill bit. The cutter bodies of essentially ellipsoidal configuration, being slightly thicker at a mid-portion thereof. Cutting elements are connected to flutes projecting above an outer surface of each cutter body. In a primary rotational direction of the drill string and drill bit, the rows abrade the bottom and side walls of a well bore as the cutter body attacks the earth formation as the drill bit is rotated. The impingement of the cutting elements of the cutter body on the earth formation imparts a secondary rotation to the cutter bodies, which secondary rotation is induced by the primary rotation. The secondary rotation allows the rows of cutting elements to engage the side wall of the bore and gauge the hole as well as abrading away material from the bottom of the well bore. A roller bearing assembly is provided for the cutter body to permit the secondary rotation, while a thrust bearing assembly assists the primary abrasive action imparted by the primary rotational movement of the rotary drill bit. A lubrication system is included in the main body structure of the drill bit wherein both the roller bearing assembly and thrust bearing assembly are lubricated.

Frear, L.

1985-11-12T23:59:59.000Z

362

Drill pipe management extends drillstring life  

SciTech Connect

Better handling procedures and frequent drill pipe inspections prolong the life of a drillstring. Crews taught to make quick visual inspections during rig moves and tripping can spot problem pipe early, thus preventing downtime or extensive repairs. Because of escalating costs of drillstring repair and replacement, Global Marine Drilling Co. organized a task force in March 1989 to define problem areas and establish new handling and maintenance procedures. The task force estimated that one 20,000-ft drillstring costs abut $600,000 and has a 7-year life span. Assuming the average rig life is 21 years, each rig will wear out three strings, totaling $1.8 million. The addition of $30,000/year for full rack inspections, repairs and downhole loss brings the total to approximately $2.4 million/rig over the 21 years. A contractor with a fleet of 25 rigs could expend $60 million on drill pipe-the construction cost of a well-equipped, 300-ft jack up rig. The task force reported on in this paper identifies four basic caused of drill pipe failures: Tool joint and tube OD wear, Internal corrosion, Fatigue cracking in the slip and internal upset areas, Physical damage to the tool joint threads and shoulders, and the tube.

Shepard, J.S. (Global Marine Drilling Co., Houston, TX (US))

1991-10-28T23:59:59.000Z

363

A new well surveying tool  

E-Print Network (OSTI)

directional well was to tip the entire rig, then block up one side of the rotary table so as to incline the uppermost joint of the drill pipe. The accuracy obtained by this method left much to be desired. The technique of controlled directional drilling... by Surveying Device for S and 19 , N and 41 . 21 3. Comparison of Measured Angles and Angles Indicated by Surveying Device for NE snd 9 , W and 45 . . . . . . . ~ 22 ABSTRNl T Ever since the advent of rotary drilling the petroleum industry has been...

Haghighi, Manuchehr Mehdizabeh

1966-01-01T23:59:59.000Z

364

Exploratory Well At Long Valley Caldera Geothermal Area (Sorey...  

Open Energy Info (EERE)

395. Notes Among these wells were exploration and monitoring wells drilled near the Fish Hatchery Springs in preparation for the siting of a second binary geothermal power...

365

Laser Drilling - Drilling with the Power of Light  

SciTech Connect

Gas Technology Institute (GTI) has been the leading investigator in the field of high power laser applications research for well construction and completion applications. Since 1997, GTI (then as Gas Research Institute- GRI) has investigated several military and industrial laser systems and their ability to cut and drill into reservoir type rocks. In this report, GTI continues its investigation with a 5.34 kW ytterbium-doped multi-clad high power fiber laser (HPFL). When compared to its competitors; the HPFL represents a technology that is more cost effective to operate, capable of remote operations, and requires considerably less maintenance and repair. Work performed under this contract included design and implementation of laboratory experiments to investigate the effects of high power laser energy on a variety of rock types. All previous laser/rock interaction tests were performed on samples in the lab at atmospheric pressure. To determine the effect of downhole pressure conditions, a sophisticated tri-axial cell was designed and tested. For the first time, Berea sandstone, limestone and clad core samples were lased under various combinations of confining, axial and pore pressures. Composite core samples consisted of steel cemented to rock in an effort to represent material penetrated in a cased hole. The results of this experiment will assist in the development of a downhole laser perforation or side tracking prototype tool. To determine how this promising laser would perform under high pressure in-situ conditions, GTI performed a number of experiments with results directly comparable to previous data. Experiments were designed to investigate the effect of laser input parameters on representative reservoir rock types of sandstone and limestone. The focus of the experiments was on laser/rock interaction under confining pressure as would be the case for all drilling and completion operations. As such, the results would be applicable to drilling, perforation, and side tracking applications. In the past, several combinations of laser and rock variables were investigated at standard conditions and reported in the literature. More recent experiments determined the technical feasibility of laser perforation on multiple samples of rock, cement and steel. The fiber laser was capable of penetrating these materials under a variety of conditions, to an appropriate depth, and with reasonable energy requirements. It was determined that fiber lasers are capable of cutting rock without causing damage to flow properties. Furthermore, the laser perforation resulted in permeability improvements on the exposed rock surface. This report has been prepared in two parts and each part may be treated as a stand-alone document. Part 1 (High Energy Laser Drilling) includes the general description of the concept and focuses on results from experiments under the ambient lab conditions. Part 2 (High Energy Laser Perforation and Completion Techniques) discusses the design and development of a customized laser pressure cell; experimental design and procedures, and the resulting data on pressure-charged samples exposed to the laser beam. An analysis provides the resulting effect of downhole pressure conditions on the laser/rock interaction process.

Iraj A. Salehi; Brian C. Gahan; Samih Batarseh

2007-02-28T23:59:59.000Z

366

NEPA COMPLIANCE SURVEY Project Information Project Title: Casing Drilling Test  

Energy.gov (U.S. Department of Energy (DOE)) Indexed Site

Casing Drilling Test Casing Drilling Test Date: 5-17-201 1 DOE Code: 6730-020-72000 Contractor Code: 8067-806 Project Lead: Marl< Duletsky Project Overview 1, Brief project description ~nclude The existing 13-1-SX-23 location and entry road will be reworldrilling rig (SST anything that could impact the rig #3). The two existing wells on the location will be capped at ground level, and a new well will be drilled environment] using water based mud. The existing rat I mouse hole on the site will be backfilled. A new 6700 ft3 reserve pit [80' long by 30' wide by 4' deep allowing for 2' of freeboard] will be constructed on location. and a 12 mm 2. Legal location liner will be installed. 3. Duration of the project 4. Major equipment to be used

367

Oil and Gas Drilling Bit Tribology  

Science Journals Connector (OSTI)

A drilling bit is used in petroleum exploration to drill a wellbore through various layers of rock formations to access oil or natural gas resources. It is engineered...1). A roller cone drill bit is categorized ...

Dr. Chih Lin Ph.D.

2013-01-01T23:59:59.000Z

368

oil-emulsion (rotary) drilling fluid  

Science Journals Connector (OSTI)

oil-emulsion (rotary) drilling fluid, oil-emulsion fluid [Used where low fluid-loss, very thin cake, and good lubrication of the drill pipe are of primary importance, such as in directional drilling ...

2014-08-01T23:59:59.000Z

369

Relating horsepower to drilling productivity  

SciTech Connect

Many technological advancements have been made in explosive products and applications over the last 15 years resulting in productivity and cost gains. However, the application of total energy (engine horsepower) in the majority of rotary drilling technology, has remained virtually unchanged over that period. While advancements have been made in components, efficiency, and types of hydraulic systems used on drills, the application of current hydraulic technology to improve drilling productivity has not been interactive with end users. This paper will investigate how traditional design assumptions, regarding typical application of horsepower in current rotary drill systems, can actually limit productivity. It will be demonstrated by numeric analysis how changing the partitioning of available hydraulic energy can optimize rotary drill productivity in certain conditions. Through cooperative design ventures with drill manufacturers, increased penetration rates ranging from 20% to 100% have been achieved. Productivity was increased initially on some rigs by careful selection of optional hydraulic equipment. Additional gains were made in drilling rates by designing the rotary hydraulic circuit to meet the drilling energies predicted by computer modeling.

Givens, R.; Williams, G.; Wingfield, B.

1996-12-31T23:59:59.000Z

370

February 2002 OCEAN DRILLING PROGRAM  

E-Print Network (OSTI)

February 2002 OCEAN DRILLING PROGRAM LEG 204 SCIENTIFIC PROSPECTUS DRILLING GAS HYDRATES ON HYDRATE 1000 Discovery Drive College Station TX 77845-9547 USA -------------------------------- Dr. Carl Drive College Station TX 77845-9547 USA #12;PUBLISHER'S NOTES Material in this publication may be copied

371

Drilling Methods | Open Energy Information  

Open Energy Info (EERE)

Drilling Methods Drilling Methods Jump to: navigation, search GEOTHERMAL ENERGYGeothermal Home Exploration Technique: Drilling Methods Details Activities (0) Areas (0) Regions (0) NEPA(5) Exploration Technique Information Exploration Group: Exploration Sub Group: None Parent Exploration Technique: Information Provided by Technique Lithology: Stratigraphic/Structural: Hydrological: Thermal: Dictionary.png Drilling Methods: No definition has been provided for this term. Add a Definition References No exploration activities found. Document # Analysis Type Applicant Geothermal Area Lead Agency District Office Field Office Mineral Manager Surface Manager Development Phase(s) Techniques CA-170-02-15 EA Mammoth Pacific Long Valley Caldera Geothermal Area BLM BLM Central California District Office BLM Bishop Field Office BLM Geothermal/Exploration Drilling Methods

372

OM300 Direction Drilling Module  

SciTech Connect

OM300 – Geothermal Direction Drilling Navigation Tool: Design and produce a prototype directional drilling navigation tool capable of high temperature operation in geothermal drilling Accuracies of 0.1° Inclination and Tool Face, 0.5° Azimuth Environmental Ruggedness typical of existing oil/gas drilling Multiple Selectable Sensor Ranges High accuracy for navigation, low bandwidth High G-range & bandwidth for Stick-Slip and Chirp detection Selectable serial data communications Reduce cost of drilling in high temperature Geothermal reservoirs Innovative aspects of project Honeywell MEMS* Vibrating Beam Accelerometers (VBA) APS Flux-gate Magnetometers Honeywell Silicon-On-Insulator (SOI) High-temperature electronics Rugged High-temperature capable package and assembly process

MacGugan, Doug

2013-08-22T23:59:59.000Z

373

low-solids oil emulsion (drilling) mud  

Science Journals Connector (OSTI)

low-solids oil emulsion (drilling) mud, low-solids oil-in-water (drilling) mud ? öl-in-Wasser-(Bohr)...m, (f) mit geringem Feststoffanteil

2014-08-01T23:59:59.000Z

374

Hydraulic Pulse Drilling  

NLE Websites -- All DOE Office Websites (Extended Search)

REV DATE DESCRIPTION ORIGINATOR REVIEWED DATE REV DATE DESCRIPTION ORIGINATOR REVIEWED DATE 0 4/13/2004 Final Report Author: J. Kolle Hunter/Theimer 4/13/2004 Document No.: TR- 053 HydroPulse(tm) Drilling Final Report Prepared by J.J. Kolle April 2004 U.S. Department of Energy Cooperative Development Agreement No. DE-FC26-FT34367 Tempress Technologies, Inc. 18858 - 72 ND Ave S. Kent, WA 98032 Disclaimer This report was prepared as an account of work sponsored by an agency of the United States Government. Neither the United States Government nor any agency thereof, nor any of their employees, makes any warranty, express or implied, or assumes any legal liability or responsibility for the accuracy, completeness, or usefulness of any information, apparatus, product, or process disclosed, or represents that its use would not

375

Single-Well and Cross-Well Seismic At Salt Wells Area (Bureau of Land  

Open Energy Info (EERE)

Single-Well and Cross-Well Seismic At Salt Wells Area (Bureau of Land Single-Well and Cross-Well Seismic At Salt Wells Area (Bureau of Land Management, 2009) Jump to: navigation, search GEOTHERMAL ENERGYGeothermal Home Exploration Activity: Single-Well and Cross-Well Seismic At Salt Wells Area (Bureau of Land Management, 2009) Exploration Activity Details Location Salt Wells Geothermal Area Exploration Technique Single-Well And Cross-Well Seismic Activity Date 2008 - 2008 Usefulness not indicated DOE-funding Unknown Exploration Basis Vulcan increased exploration efforts in the summer and fall of 2008, during which time the company drilled two temperature gradient holes (86-15 O on Pad 1 and 17-16 O on Pad 3); conducted seismic, gravity and magnetotelluric surveys; and drilled deep exploration wells at Pads 6 and 8 and binary

376

Becker, K., Malone, M.J., et al., 1998 Proceedings of the Ocean Drilling Program, Initial Reports, Vol. 174B  

E-Print Network (OSTI)

(drill-pipe measurement from rig floor, mbrf): 4457.1 Total depth (drill-pipe measurement from rig floor, mbrf): 4526.6 Distance between rig floor and sea level (m): 11.6 Water depth (drill-pipe measurement Program (ODP) Leg 45, and the sediments at the site were not recov- ered well with the rotary core barrel

377

Drilling Waste Management Fact Sheet: Slurry Injection of Drilling Wastes  

NLE Websites -- All DOE Office Websites (Extended Search)

Slurry Injection Slurry Injection Fact Sheet - Slurry Injection of Drilling Wastes Underground Injection of Drilling Wastes Several different approaches are used for injecting drilling wastes into underground formations for permanent disposal. Salt caverns are described in a separate fact sheet. This fact sheet focuses on slurry injection technology, which involves grinding or processing solids into small particles, mixing them with water or some other liquid to make a slurry, and injecting the slurry into an underground formation at pressures high enough to fracture the rock. The process referred to here as slurry injection has been given other designations by different authors, including slurry fracture injection (this descriptive term is copyrighted by a company that provides slurry injection services), fracture slurry injection, drilled cuttings injection, cuttings reinjection, and grind and inject.

378

Handbook of Best Practices for Geothermal Drilling | Open Energy  

Open Energy Info (EERE)

Handbook of Best Practices for Geothermal Drilling Handbook of Best Practices for Geothermal Drilling Jump to: navigation, search OpenEI Reference LibraryAdd to library Report: Handbook of Best Practices for Geothermal Drilling Abstract This Handbook is a description of the complex process that comprises drilling a geothermal well. The focus of the detailed Chapters covering various aspects of the process (casing design, cementing, logging and instrumentation, etc) is on techniques and hardware that have proven successful in geothermal reservoirs around the world. The Handbook will eventually be linked to the Geothermal Implementing Agreement (GIA) web site, with the hope and expectation that it can be continually updated as new methods are demonstrated or proven. Authors John Finger and Doug Blankenship

379

Drilling Techniques | Open Energy Information  

Open Energy Info (EERE)

Page Page Edit with form History Facebook icon Twitter icon » Drilling Techniques Jump to: navigation, search GEOTHERMAL ENERGYGeothermal Home Exploration Technique: Drilling Techniques Details Activities (0) Areas (0) Regions (0) NEPA(20) Exploration Technique Information Exploration Group: Drilling Techniques Exploration Sub Group: None Parent Exploration Technique: Exploration Techniques Information Provided by Technique Lithology: Identify lithology and mineralization, provide core samples and rock cuttings Stratigraphic/Structural: Retrieved samples can be used to identify stratigraphy and structural features such as fracture networks or faults Hydrological: -Water samples can be used for geochemical analysis -Fluid pressures can be used to estimate flow rates

380

Simulation study on the CO2-driven enhanced gas recovery with sequestration versus the re-fracturing treatment of horizontal wells in the U.S. unconventional shale reservoirs  

Science Journals Connector (OSTI)

Abstract It is proposed that very low permeability formations are possible candidates for CO2 sequestration. Further, experimental studies have shown that shale formations have huge affinity to adsorb CO2, the order of 5 to 1 compared to the methane. Therefore, potential sequestration of CO2 in shale formations leading to enhanced gas recovery (EGR) will be a promising while challenging target for the oil and gas industry. On the other side, hydraulic re-fracturing treatment of shale gas wells is currently gaining more attention due to the poor performance of shale gas reservoirs after a couple years of production. Hence, investigating and comparing the performance of CO2-EGR with the re-fracturing treatment is essential for the future economic viability of depleted shale gas reservoirs. This paper presents a systematic comparison of the effect of these two processes on improving gas production performance of unconventional reservoirs, which is not well understood and has not been studied thoroughly in the literature. In this paper, a shale gas field data has been evaluated and incorporated in our simulations for both CO2-EGR and re-fracturing treatment purposes. Numerical simulations are performed using local grid refinement (LGR) in order to accurately model the non-linear pressure drop. Also, a dual-porosity/dual-permeability model is incorporated in the reservoir simulation model. Further, the uncertainties associated with inter-related set of geologic and engineering parameters are evaluated and quantified for re-fracturing treatment through several simulation runs. This comprehensive sensitivity study helps in understanding the key reservoir and fracture properties that affect the production performance and enhanced gas recovery in shale gas reservoirs. The results showed that re-fracturing treatment outperforms CO2-EGR due to the pronounced effect on cumulative methane gas production. Moreover, the sensitivity analysis showed that the characteristics of reservoir matrix including permeability and porosity are the most influential parameters for re-fracturing treatment. The findings of this study recommend hydraulic re-fracturing of shale reservoirs at first for enhancing gas production followed by CO2 injection at a later time. This work provides field operators with more insight into maximizing gas recovery from unconventional shale gas reservoirs using re-fracturing stimulation, CO2 injection, or a combination of both methods.

Mohammad O. Eshkalak; Emad W. Al-Shalabi; Alireza Sanaei; Umut Aybar; Kamy Sepehrnoori

2014-01-01T23:59:59.000Z

Note: This page contains sample records for the topic "horizontal wells drilling" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


381

U.S. Real Cost per Foot of Crude Oil, Natural Gas, and Dry Wells...  

Annual Energy Outlook 2012 (EIA)

Foot of Crude Oil, Natural Gas, and Dry Wells Drilled (Dollars per Foot) U.S. Real Cost per Foot of Crude Oil, Natural Gas, and Dry Wells Drilled (Dollars per Foot) Decade Year-0...

382

Smaller Footprint Drilling System for Deep and Hard Rock Environments; Feasibility of Ultra-High-Speed Diamond Drilling  

SciTech Connect

The two phase program addresses long-term developments in deep well and hard rock drilling. TerraTek believes that significant improvements in drilling deep hard rock will be obtained by applying ultra-high rotational speeds (greater than 10,000 rpm). The work includes a feasibility of concept research effort aimed at development that will ultimately result in the ability to reliably drill 'faster and deeper' possibly with smaller, more mobile rigs. The principle focus is on demonstration testing of diamond bits rotating at speeds in excess of 10,000 rpm to achieve high rate of penetration (ROP) rock cutting with substantially lower inputs of energy and loads. The significance of the 'ultra-high rotary speed drilling system' is the ability to drill into rock at very low weights on bit and possibly lower energy levels. The drilling and coring industry today does not practice this technology. The highest rotary speed systems in oil field and mining drilling and coring today run less than 10,000 rpm - usually well below 5,000 rpm. This document provides the progress through two phases of the program entitled 'Smaller Footprint Drilling System for Deep and Hard Rock Environments: Feasibility of Ultra-High-Speed Diamond Drilling' for the period starting 30 June 2003 and concluding 31 March 2009. The accomplishments of Phases 1 and 2 are summarized as follows: (1) TerraTek reviewed applicable literature and documentation and convened a project kick-off meeting with Industry Advisors in attendance (see Black and Judzis); (2) TerraTek designed and planned Phase I bench scale experiments (See Black and Judzis). Improvements were made to the loading mechanism and the rotational speed monitoring instrumentation. New drill bit designs were developed to provided a more consistent product with consistent performance. A test matrix for the final core bit testing program was completed; (3) TerraTek concluded small-scale cutting performance tests; (4) Analysis of Phase 1 data indicated that there is decreased specific energy as the rotational speed increases; (5) Technology transfer, as part of Phase 1, was accomplished with technical presentations to the industry (see Judzis, Boucher, McCammon, and Black); (6) TerraTek prepared a design concept for the high speed drilling test stand, which was planned around the proposed high speed mud motor concept. Alternative drives for the test stand were explored; a high speed hydraulic motor concept was finally used; (7) The high speed system was modified to accommodate larger drill bits than originally planned; (8) Prototype mud turbine motors and the high speed test stand were used to drive the drill bits at high speed; (9) Three different rock types were used during the testing: Sierra White granite, Crab Orchard sandstone, and Colton sandstone. The drill bits used included diamond impregnated bits, a polycrystalline diamond compact (PDC) bit, a thermally stable PDC (TSP) bit, and a hybrid TSP and natural diamond bit; and (10) The drill bits were run at rotary speeds up to 5500 rpm and weight on bit (WOB) to 8000 lbf. During Phase 2, the ROP as measured in depth of cut per bit revolution generally increased with increased WOB. The performance was mixed with increased rotary speed, with the depth cut with the impregnated drill bit generally increasing and the TSP and hybrid TSP drill bits generally decreasing. The ROP in ft/hr generally increased with all bits with increased WOB and rotary speed. The mechanical specific energy generally improved (decreased) with increased WOB and was mixed with increased rotary speed.

TerraTek, A Schlumberger Company

2008-12-31T23:59:59.000Z

383

REVISED HYDROGEN SULFIDE DRILLING CONTINGENCY PLAN  

E-Print Network (OSTI)

REVISED HYDROGEN SULFIDE DRILLING CONTINGENCY PLAN OCEAN DRILLING PROGRAM TEXAS A&M UNIVERSITY;PREFACE Attached is the "REVISED HYDROGEN SULFIDE DRILLING CONTINGENCY PLAN" that will be used for ODP coring and drilling operations on legs where hydrogen sulfide is likely to be encountered. Prior

384

Improved Miscible Nitrogen Flood Performance Utilizing Advanced Reservoir Characterization and Horizontal Laterals in a Class I Reservoir - East Binger (Marchand) Unit  

SciTech Connect

The DOE-sponsored project at the East Binger Unit is an investigation into the benefits of reservoir characterization and horizontal wells in this particular setting of geologic and recovery method. The geologic setting is a tight (average porosity of 7% and average permeability of less than 1 millidarcy) Pennsylvanian-age sandstone at about 10,000 feet, and the recovery method is a miscible nitrogen flood. The projected oil recovery of the East Binger Unit, prior to the initiation of this project, was about 25%. Gravity segregation of nitrogen and crude oil was believed to be the principal cause of the poor sweep efficiency, and it was envisioned that with horizontal producing wells in the lower portion of the reservoir and horizontal injection wells near the top, the process could be converted from a lateral displacement process to a vertical displacement/gravity assisted process. Through the characterization and field development work completed in Budget Periods 1 and 2, Binger Operations, LLC (BOL) has developed a different interpretation of the sweep problem as well as a different approach to improving recovery. The sweep problem is now believed to be one of an areal nature, due to a combination of natural and hydraulic fracturing. Vertical wells have provided a much better economic return than have the horizontal wells. The natural and hydraulic fracturing manifests itself as a direction of higher permeability, and the flood is being converted to a line drive flood aligned with this orientation. Consistent with this concept, horizontal wells have been drilled along the line of the fracture orientation, such that hydraulic fracturing leads to 'longitudinal' fractures, in line with the wellbore. As such, the hydraulically fractured horizontal wells are not significantly different than hydraulically fractured vertical wells - save for the potential for a much longer fracture face. This Topical Report contains data from new wells, plus new and updated production, pressure, and gas analysis data that was not included in the Topical Report provided at the end of Budget Period 1. The analysis and interpretation of these data are provided in the many technical reports submitted throughout this project.

Joe Sinner

2004-06-30T23:59:59.000Z

385

Tool Wear in Friction Drilling  

SciTech Connect

This study investigated the wear of carbide tools used in friction drilling, a nontraditional hole-making process. In friction drilling, a rotating conical tool uses the heat generated by friction to soften and penetrate a thin workpiece and create a bushing without generating chips. The wear of a hard tungsten carbide tool used for friction drilling a low carbon steel workpiece has been investigated. Tool wear characteristics were studied by measuring its weight change, detecting changes in its shape with a coordinate measuring machine, and making observations of wear damage using scanning electron microscopy. Energy dispersive spectroscopy was applied to analyze the change in chemical composition of the tool surface due to drilling. In addition, the thrust force and torque during drilling and the hole size were measured periodically to monitor the effects of tool wear. Results indicate that the carbide tool is durable, showing minimal tool wear after drilling 11000 holes, but observations also indicate progressively severe abrasive grooving on the tool tip.

Miller, Scott F [ORNL; Blau, Peter Julian [ORNL; Shih, Albert J. [University of Michigan

2007-01-01T23:59:59.000Z

386

Four rigs refurbished for West Africa drilling  

SciTech Connect

In April and May 1990, Shell Petroleum Development Co. of Nigeria Ltd. awarded Noble Drilling West Africa Inc. four separate contracts to drill oil and gas wells in the inland waterways of Nigeria. The contracted rigs included a shallow water jack up, the NN-1, and three posted barges, the Gene Rosser, the Chuck Syring, and the Lewis Dugger. The jack up was built in 1978, and the three posted barges are 1980s vintage. Three of the rigs have been idle for a number of years. The Shell Nigeria contracts required major modifications to the rigs before putting them into international service. Noble replaced or refurbished all major pieces of equipment in the drilling, power, and service systems on the rigs. Rig crews serviced all other equipment. A significant amount of general service piping and electrical wiring was replaced. Each rig also required additional motor control centers to support the new drilling and mud processing equipment. Alfa-Laval waste-heat water desalination plants and new sewage treatment units were installed on all four rigs. Because of the tidal variances and high silt conditions expected in the African waterways, all engine cooling systems were converted from heat exchangers to radiators. Rotary tables were made common on all rigs at 37 1/2 in. Noble had all traveling equipment completely inspected and modified as necessary. Strict attention was paid to certification and documentation of all equipment. Safety upgrades conformed to both Shell and Noble standards. Fire and gas detection systems were installed throughout each rig. Water and foam deluge systems were installed in the wellhead areas, and new foam systems and monitors were installed on the helldecks.

Not Available

1991-06-10T23:59:59.000Z

387

Microhole Arrays Drilled With Advanced Abrasive Slurry Jet Technology To  

Open Energy Info (EERE)

Microhole Arrays Drilled With Advanced Abrasive Slurry Jet Technology To Microhole Arrays Drilled With Advanced Abrasive Slurry Jet Technology To Efficiently Exploit Enhanced Geothermal Systems Geothermal Project Jump to: navigation, search Last modified on July 22, 2011. Project Title Microhole Arrays Drilled With Advanced Abrasive Slurry Jet Technology To Efficiently Exploit Enhanced Geothermal Systems Project Type / Topic 1 Recovery Act: Enhanced Geothermal Systems Component Research and Development/Analysis Project Type / Topic 2 Drilling Systems Project Description This project proposes to develop a cost-effective microhole drilling and completion technology with the Flash Abrasive Slurry Jet (ASJ) system and optimize it to maximize the efficiency of fluid circulation and heat removal for Enhanced Geothermal Systems (EGS). The proposed approach is expected to address the key obstacles that currently prevent EGS from becoming a technically feasible, commercially viable major contributor for electricity generation, namely: (1) reduce costs for drilling and well completion and (2) increase the volume of hot rock from which heat can be extracted.

388

Applications of CBR in Oil Well Drilling: A General Overview  

Science Journals Connector (OSTI)

This overview of different applications of CBR in petroleum engineering is based on a survey and comparative evaluation of different successful applications of CBR. The number of papers and research groups is ...

Samad Valipour Shokouhi; Agnar Aamodt; Pål Skalle

2010-01-01T23:59:59.000Z

389

The Temperature Prediction in Deepwater Drilling of Vertical Well  

E-Print Network (OSTI)

.................................................................................................. 30 3.4 Geothermal Gradient ................................................................................ 30 3.5 Overall Heat Transfer Coefficient ............................................................ 30... ............................................................................................ 47 vii ? Page 5.2 Conservation Of Energy ........................................................................... 47 5.3 Steady-state Heat Transfer Model...

Feng, Ming

2012-07-16T23:59:59.000Z

390

U.S. Natural Gas Exploratory and Developmental Wells Drilled...  

Annual Energy Outlook 2012 (EIA)

Year Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 1973 519 454 494 546 598 543 615 690 574 694 616 590 1974 686 545 657 624 604 595 604 554 569 633 526 541 1975 613 539 534 587...

391

U.S. Natural Gas Exploratory and Developmental Wells Drilled...  

Annual Energy Outlook 2012 (EIA)

Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1940's 3,363 1950's 3,439 3,438 3,514 3,968 4,038 4,266 4,531 4,475 5,005 4,931 1960's 5,149 5,486...

392

ECONOMIC RECOVERY OF OIL TRAPPED AT FAN MARGINS USING HIGH ANGLE WELLS AND MULTIPLE HYDRAULIC FRACTURES  

SciTech Connect

This project attempts to demonstrate the effectiveness of exploiting thin-layered, low-energy deposits at the distal margin of a prograding turbidite complex through the use of hydraulically fractured horizontal or high-angle wells. The combination of a horizontal or high-angle well and hydraulic fracturing will allow greater pay exposure than can be achieved with conventional vertical wells while maintaining vertical communication between thin interbedded layers and the wellbore. A high-angle well will be drilled in the fan-margin portion of a slope-basin clastic reservoir and will be completed with multiple hydraulic-fracture treatments. Geologic modeling, reservoir characterization, and fine-grid reservoir simulation will be used to select the well location and orientation. Design parameters for the hydraulic-fracture treatments will be determined, in part, by fracturing an existing test well. Fracture azimuth will be predicted by passive seismic monitoring of a fracture-stimulation treatment in the test well using logging tools in an offset well.

Mike L. Laue

1998-11-06T23:59:59.000Z

393

The Performance of Fractured Horizontal Well in Tight Gas Reservoir  

E-Print Network (OSTI)

?, including tight gas, gas/oil shale, oil sands, and coal-bed methane. North America has a substantial growth in its unconventional oil and gas market over the last two decades. The primary reason for that growth is because North America, being a mature...

Lin, Jiajing

2012-02-14T23:59:59.000Z

394

Chemical wellbore plug for zone isolation in horizontal wells  

E-Print Network (OSTI)

of chemicals that could be used to make wellbore plugs with sufficiently high holding pressures. Three chemicals, used in the oil industry for gas and/or water shut-off, were selected for the study. The commercial names of these chemicals were SEAL, PERMASEAL...

Saavedra, Nestor Fernando

1996-01-01T23:59:59.000Z

395

Production decline analysis of horizontal well in gas shale reservoirs.  

E-Print Network (OSTI)

??The major factor influencing the increase of natural gas use is the rise in its global demand. Due to the relentlessly increasing demand, there have… (more)

Adekoya, Folarin.

2009-01-01T23:59:59.000Z

396

Analytical modeling of contaminant transport and horizontal well hydraulics  

E-Print Network (OSTI)

transport from one-, two-, and three-dimensional finite sources in a finite-thickness aquifer using Green's function method. A library of unpublished analytical solutions with different finite source geometry is provided. A graphically integrated software...

Park, Eungyu

2004-09-30T23:59:59.000Z

397

Damage tolerance of well-completion and stimulation techniques in coalbed methane reservoirs  

SciTech Connect

Coalbed methane (CBM) reservoirs are characterized as naturally fractured, dual porosity, low permeability, and water saturated gas reservoirs. Initially, the gas, water and coal are at thermodynamic equilibrium under prevailing reservoir conditions. Dewatering is essential to promote gas production. This can be accomplished by suitable completion and stimulation techniques. This paper investigates the efficiency and performance of the openhole cavity, hydraulic fractures, frack and packs, and horizontal wells as potential completion methods which may reduce formation damage and increase the productivity in coalbed methane reservoirs. Considering the dual porosity nature of CBM reservoirs, numerical simulations have been carried out to determine the formation damage tolerance of each completion and, stimulation approach. A new comparison parameter named as the normalized productivity index is defined as the ratio of the productivity index of a stimulated well to that of a nondamaged vertical well as a function of time. Typical scenarios have been considered to evaluate the CBM properties, including reservoir heterogeneity, anisotropy, and formation damage, for their effects on this index over the production time. The results for each stimulation technique show that the value of the index declines over the time of production with a rate which depends upon the applied technique and the prevailing reservoir conditions. The results also show that horizontal wells have the best performance if drilled orthogonal to the butt cleats. Open-hole cavity completions outperform vertical fractures if the fracture conductivity is reduced by any damage process. When vertical permeability is much lower than horizontal permeability, production of vertical wells will improve while productivity of horizontal wells will decrease.

Jahediesfanjani, H.; Civan, F. [University of Oklahoma, Norman, OK (United States)

2005-09-01T23:59:59.000Z

398

JOIDES Resolution Drill Ship Drill into Indian Ridge MOHO Hole Cleaning Study  

E-Print Network (OSTI)

The Integrated Ocean Drilling Program (IODP) uses a variety of technology for use in its deep water scientific research, including the Joint Oceanographic Institutions for Deep Earth Sampling (JOIDES) Resolution (JR) drill ship. The JR drill ship...

Lindanger, Catharina

2014-05-03T23:59:59.000Z

399

84 Scientific Drilling, Special Issue No.1, 2007 Part 4 : The Physics of Earthquake RupturePart 4 : The Physics of Earthquake Rupture  

E-Print Network (OSTI)

Main Hole. The Long Valley Exploratory Well (LVEW) is a 3.0-km- deep research drill hole located near the center of Long Valley caldera in eastern California. The well was drilled in a series of stages beginning of the International Continental Drilling Program (ICDP) Long Valley Coring Project. Prior to the final stage

Waldhauser, Felix

400

DOE-Sponsored Project Pushes the Limits of Seismic-While-Drilling  

Energy.gov (U.S. Department of Energy (DOE)) Indexed Site

Project Pushes the Limits of Seismic-While-Drilling Project Pushes the Limits of Seismic-While-Drilling Technology DOE-Sponsored Project Pushes the Limits of Seismic-While-Drilling Technology August 12, 2009 - 1:00pm Addthis Washington, DC - In a project sponsored by the U.S. Department of Energy, Technology International Inc. has developed a breakthrough borehole imaging system that stands on the cusp of commercialization. By pushing the limits of seismic-while-drilling technology, the patent-pending SeismicPULSER system provides more accurate geo-steering for the discovery of new oil and natural gas reserves, facilitating new field development and improving well economics. Drill-bit seismic-while-drilling techniques use a downhole acoustic source and receivers at the surface to create real-time images that allow

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401

Drill wear: its effect on the diameter of drilled holes  

E-Print Network (OSTI)

drills are made of oae of two differeat materials. The most common material in use today 1s aa 18-4-1 type of high speed steel. This steel contains about O. VS per cent carboa, 18. 00 per eeet tungstea, 4. 00 per cent chromium, and 1. 10 per eeet... vanadium. The primary advaatage of steel of this type is its ability to maintain its cutt1ng edge and haxdaess at high tempexatures. Besides beiag used for drills, this steel finds applicntioa in waay other tools such as willing cutters, taps, reamers...

Reichert, William Frederick

2012-06-07T23:59:59.000Z

402

April 25, 1997: Yucca Mountain exploratory drilling | Department...  

Office of Environmental Management (EM)

April 25, 1997: Yucca Mountain exploratory drilling April 25, 1997: Yucca Mountain exploratory drilling April 25, 1997: Yucca Mountain exploratory drilling April 25, 1997 Workers...

403

Soda Lake Well Lithology Data and Geologic Cross-Sections  

SciTech Connect

Comprehensive catalogue of drill?hole data in spreadsheet, shapefile, and Geosoft database formats. Includes XYZ locations of well heads, year drilled, type of well, operator, total depths, well path data (deviations), lithology logs, and temperature data. Plus, 13 cross?sections in Adobe Illustrator format.

Faulds, James E.

2013-12-31T23:59:59.000Z

404

SMALLER FOOTPRINT DRILLING SYSTEM FOR DEEP AND HARD ROCK ENVIRONMENTS; FEASIBILITY OF ULTRA-HIGH SPEED DIAMOND DRILLING  

SciTech Connect

The two phase program addresses long-term developments in deep well and hard rock drilling. TerraTek believes that significant improvements in drilling deep hard rock will be obtained by applying ultra-high (greater than 10,000 rpm) rotational speeds. The work includes a feasibility of concept research effort aimed at development and test results that will ultimately result in the ability to reliably drill ''faster and deeper'' possibly with rigs having a smaller footprint to be more mobile. The principle focus is on demonstration testing of diamond bits rotating at speeds in excess of 10,000 rpm to achieve high rate of penetration rock cutting with substantially lower inputs of energy and loads. The project draws on TerraTek results submitted to NASA's ''Drilling on Mars'' program. The objective of that program was to demonstrate miniaturization of a robust and mobile drilling system that expends small amounts of energy. TerraTek successfully tested ultrahigh speed ({approx}40,000 rpm) small kerf diamond coring. Adaptation to the oilfield will require innovative bit designs for full hole drilling or continuous coring and the eventual development of downhole ultra-high speed drives. For domestic operations involving hard rock and deep oil and gas plays, improvements in penetration rates is an opportunity to reduce well costs and make viable certain field developments. An estimate of North American hard rock drilling costs is in excess of $1,200 MM. Thus potential savings of $200 MM to $600 MM are possible if drilling rates are doubled [assuming bit life is reasonable]. The net result for operators is improved profit margin as well as an improved position on reserves. The significance of the ''ultra-high rotary speed drilling system'' is the ability to drill into rock at very low weights on bit and possibly lower energy levels. The drilling and coring industry today does not practice this technology. The highest rotary speed systems in oil field and mining drilling and coring today run less than 10,000 rpm--usually well below 5,000 rpm. This document details the progress to date on the program entitled ''SMALLER FOOTPRINT DRILLING SYSTEM FOR DEEP AND HARD ROCK ENVIRONMENTS; FEASIBILITY OF ULTRA-HIGH SPEED DIAMOND DRILLING'' for the period starting June 23, 2003 through September 30, 2004. (1) TerraTek has reviewed applicable literature and documentation and has convened a project kick-off meeting with Industry Advisors in attendance. (2) TerraTek has designed and planned Phase I bench scale experiments. Some difficulties in obtaining ultra-high speed motors for this feasibility work were encountered though they were sourced mid 2004. (3) TerraTek is progressing through Task 3 ''Small-scale cutting performance tests''. Some improvements over early NASA experiments have been identified.

Alan Black; Arnis Judzis

2004-10-01T23:59:59.000Z

405

SMALLER FOOTPRINT DRILLING SYSTEM FOR DEEP AND HARD ROCK ENVIRONMENTS; FEASIBILITY OF ULTRA-HIGH SPEED DIAMOND DRILLING  

SciTech Connect

The two phase program addresses long-term developments in deep well and hard rock drilling. TerraTek believes that significant improvements in drilling deep hard rock will be obtained by applying ultra-high (greater than 10,000 rpm) rotational speeds. The work includes a feasibility of concept research effort aimed at development and test results that will ultimately result in the ability to reliably drill ''faster and deeper'' possibly with rigs having a smaller footprint to be more mobile. The principle focus is on demonstration testing of diamond bits rotating at speeds in excess of 10,000 rpm to achieve high rate of penetration rock cutting with substantially lower inputs of energy and loads. The project draws on TerraTek results submitted to NASA's ''Drilling on Mars'' program. The objective of that program was to demonstrate miniaturization of a robust and mobile drilling system that expends small amounts of energy. TerraTek successfully tested ultrahigh speed ({approx}40,000 rpm) small kerf diamond coring. Adaptation to the oilfield will require innovative bit designs for full hole drilling or continuous coring and the eventual development of downhole ultra-high speed drives. For domestic operations involving hard rock and deep oil and gas plays, improvements in penetration rates is an opportunity to reduce well costs and make viable certain field developments. An estimate of North American hard rock drilling costs is in excess of $1,200 MM. Thus potential savings of $200 MM to $600 MM are possible if drilling rates are doubled [assuming bit life is reasonable]. The net result for operators is improved profit margin as well as an improved position on reserves. The significance of the ''ultra-high rotary speed drilling system'' is the ability to drill into rock at very low weights on bit and possibly lower energy levels. The drilling and coring industry today does not practice this technology. The highest rotary speed systems in oil field and mining drilling and coring today run less than 10,000 rpm--usually well below 5,000 rpm. This document details the progress to date on the program entitled ''SMALLER FOOTPRINT DRILLING SYSTEM FOR DEEP AND HARD ROCK ENVIRONMENTS; FEASIBILITY OF ULTRA-HIGH SPEED DIAMOND DRILLING'' for the period starting June 23, 2003 through September 30, 2004. TerraTek has reviewed applicable literature and documentation and has convened a project kick-off meeting with Industry Advisors in attendance. TerraTek has designed and planned Phase I bench scale experiments. Some difficulties in obtaining ultra-high speed motors for this feasibility work were encountered though they were sourced mid 2004. TerraTek is progressing through Task 3 ''Small-scale cutting performance tests''. Some improvements over early NASA experiments have been identified.

Alan Black; Arnis Judzis

2004-10-01T23:59:59.000Z

406

Smaller Footprint Drilling System for Deep and Hard Rock Environments; Feasibility of Ultra-High-Speed Diamond Drilling  

SciTech Connect

The two phase program addresses long-term developments in deep well and hard rock drilling. TerraTek believes that significant improvements in drilling deep hard rock will be obtained by applying ultra-high rotational speeds (greater than 10,000 rpm). The work includes a feasibility of concept research effort aimed at development that will ultimately result in the ability to reliably drill ''faster and deeper'' possibly with smaller, more mobile rigs. The principle focus is on demonstration testing of diamond bits rotating at speeds in excess of 10,000 rpm to achieve high rate of penetration (ROP) rock cutting with substantially lower inputs of energy and loads. The significance of the ultra-high rotary speed drilling system is the ability to drill into rock at very low weights on bit and possibly lower energy levels. The drilling and coring industry today does not practice this technology. The highest rotary speed systems in oil field and mining drilling and coring today run less than 10,000 rpm--usually well below 5,000 rpm. This document details the progress to date on the program entitled ''Smaller Footprint Drilling System for Deep and Hard Rock Environments: Feasibility of Ultra-High-Speed Diamond Drilling'' for the period starting 1 October 2004 through 30 September 2005. Additionally, research activity from 1 October 2005 through 28 February 2006 is included in this report: (1) TerraTek reviewed applicable literature and documentation and convened a project kick-off meeting with Industry Advisors in attendance. (2) TerraTek designed and planned Phase I bench scale experiments. Some difficulties continue in obtaining ultra-high speed motors. Improvements have been made to the loading mechanism and the rotational speed monitoring instrumentation. New drill bit designs have been provided to vendors for production. A more consistent product is required to minimize the differences in bit performance. A test matrix for the final core bit testing program has been completed. (3) TerraTek is progressing through Task 3 ''Small-scale cutting performance tests''. (4) Significant testing has been performed on nine different rocks. (5) Bit balling has been observed on some rock and seems to be more pronounces at higher rotational speeds. (6) Preliminary analysis of data has been completed and indicates that decreased specific energy is required as the rotational speed increases (Task 4). This data analysis has been used to direct the efforts of the final testing for Phase I (Task 5). (7) Technology transfer (Task 6) has begun with technical presentations to the industry (see Judzis).

Arnis Judzis; Alan Black; Homer Robertson

2006-03-01T23:59:59.000Z

407

Deep drilling data Raft River geothermal area, Idaho | Open Energy  

Open Energy Info (EERE)

drilling data Raft River geothermal area, Idaho drilling data Raft River geothermal area, Idaho Jump to: navigation, search GEOTHERMAL ENERGYGeothermal Home Report: Deep drilling data Raft River geothermal area, Idaho Details Activities (2) Areas (1) Regions (0) Abstract: Stratigraphy and geophysical logs of three petroleum test boreholes in the Raft River Valley are presented. The geophysical logs include: temperature, resistivity, spontaneous potential, gamma, caliper, and acoustic logs. Author(s): Oriel, S. S.; Williams, P. L.; Covington, H. R.; Keys, W. S.; Shaver, K. C. Published: DOE Information Bridge, 1/1/1978 Document Number: Unavailable DOI: 10.2172/6272996 Source: View Original Report Exploratory Well At Raft River Geothermal Area (1975) Exploratory Well At Raft River Geothermal Area (1976) Raft River Geothermal Area

408

Drilling/producing depths; Two records and a revision  

SciTech Connect

This paper reports that record depths for natural gas or oil well drilling or producing continue to be rare occurrences, although one or two still come in each year. Records fell in Texas Railroad Commission (RRC) District 9 and in the California area of the Minerals Management Service (MMS) Pacific Outer Continental Shelf (OCS) in 1990. Deep drilling and production has traditionally been defined as well depths greater than 15,000 ft. Smith Tool reported that 9.4% of all active rotary rigs were dedicated to targets below 15,000 ft at the beginning of 1991. Deep rigs had dropped to 8.1% by year-end 1991, but remained above the 1989 and 1990 levels of 8.4 and 7.6%, respectively. In 1988 about 11% of active rigs were drilling deep at any given time.

Not Available

1992-02-01T23:59:59.000Z

409

Smaller Footprint Drilling System for  

NLE Websites -- All DOE Office Websites (Extended Search)

Oil & Natural Gas Technology Oil & Natural Gas Technology DOE Award No.: DE-FC26-03NT15401 Final Report Smaller Footprint Drilling System for Deep and Hard Rock Environments; Feasibility of Ultra-High-Speed Diamond Drilling Submitted by: TerraTek, A Schlumberger Company 1935 Fremont Drive Salt Lake City, UT 84104 Prepared for: United States Department of Energy National Energy Technology Laboratory 2 February 2010 Office of Fossil Energy Feasibility of Ultra-High Speed Diamond Drilling DE-FC26-03NT15401 ii DISCLAIMER This report was prepared as an account of work sponsored by an agency of the United States Government. Neither the United States Government nor any agency thereof, nor any of their employees, makes any warranty, express or implied, or assumes any legal liability or

410

RECIPIENT:Potter Drilling Inc  

Energy.gov (U.S. Department of Energy (DOE)) Indexed Site

Potter Drilling Inc Potter Drilling Inc u.s. DEPARTUEN T OF ENERG¥ EERE PROJECT MANAGEMENT CENT ER NEPA DEIERl\IINATION PROJECr TITLE: Development of a Hydrothermal Spallation Drilling System for EGS Page 1 0[2 STATE: CA Funding Opportunity Announ<:ement Number Procurement Instrument Number NEPA Control Number CID Number OE·PS36-09G099016 OE· EE0002746 ~FO . 10 - [r,,~ G02746 Based on my review of the information concerning the proposed action, as NEPA ComplianC:f Offkrr (authorized under DOE Order 451.IA), I have made the following determination: ex. EA, EIS APPENDIX AND NUMBER: Description: A9 Information gathering (including, but not limited 10, literature surveys, inventories, audits), data analysis (including computer modeling), document preparation (such as conceptual design or feasibility studies, analytical energy supply

411

Microhole High-Pressure Jet Drill for Coiled Tubing  

SciTech Connect

Tempress Small Mechanically-Assisted High-Pressure Waterjet Drilling Tool project centered on the development of a downhole intensifier (DHI) to boost the hydraulic pressure available from conventional coiled tubing to the level required for high-pressure jet erosion of rock. We reviewed two techniques for implementing this technology (1) pure high-pressure jet drilling and (2) mechanically-assisted jet drilling. Due to the difficulties associated with modifying a downhole motor for mechanically-assisted jet drilling, it was determined that the pure high-pressure jet drilling tool was the best candidate for development and commercialization. It was also determined that this tool needs to run on commingled nitrogen and water to provide adequate downhole differential pressure and to facilitate controlled pressure drilling and descaling applications in low pressure wells. The resulting Microhole jet drilling bottomhole assembly (BHA) drills a 3.625-inch diameter hole with 2-inch coil tubing. The BHA consists of a self-rotating multi-nozzle drilling head, a high-pressure rotary seal/bearing section, an intensifier and a gas separator. Commingled nitrogen and water are separated into two streams in the gas separator. The water stream is pressurized to 3 times the inlet pressure by the downhole intensifier and discharged through nozzles in the drilling head. The energy in the gas-rich stream is used to power the intensifier. Gas-rich exhaust from the intensifier is conducted to the nozzle head where it is used to shroud the jets, increasing their effective range. The prototype BHA was tested at operational pressures and flows in a test chamber and on the end of conventional coiled tubing in a test well. During instrumented runs at downhole conditions, the BHA developed downhole differential pressures of 74 MPa (11,000 psi, median) and 90 MPa (13,000 psi, peaks). The median output differential pressure was nearly 3 times the input differential pressure available from the coiled tubing. In a chamber test, the BHA delivered up to 50 kW (67 hhp) hydraulic power. The tool drilled uncertified class-G cement samples cast into casing at a rate of 0.04 to 0.17 m/min (8 to 33 ft/hr), within the range projected for this tool but slower than a conventional PDM. While the tool met most of the performance goals, reliability requires further improvement. It will be difficult for this tool, as currently configured, to compete with conventional positive displacement downhole motors for most coil tubing drill applications. Mechanical cutters on the rotating nozzle head would improve cutting. This tool can be easily adapted for well descaling operations. A variant of the Microhole jet drilling gas separator was further developed for use with positive displacement downhole motors (PDM) operating on commingled nitrogen and water. A fit-for-purpose motor gas separator was designed and yard tested within the Microhole program. Four commercial units of that design are currently involved in a 10-well field demonstration with Baker Oil Tools in Wyoming. Initial results indicate that the motor gas separators provide significant benefit.

Ken Theimer; Jack Kolle

2007-06-30T23:59:59.000Z

412

Laser Drilling - Drilling with the Power of Light  

SciTech Connect

Gas Technology Institute (GTI) has been the leading investigator in the field of high power laser applications research for well construction and completion applications. Since 1997, GTI (then as Gas Research Institute) has investigated several military and industrial laser systems and their ability to cut and drill into reservoir type rocks. In this report, GTI continues its investigation with a recently acquired 5.34 kW ytterbium-doped multi-clad high power fiber laser (HPFL). The HPFL represents a potentially disruptive technology that, when compared to its competitors, is more cost effective to operate, capable of remote operations, and requires considerably less maintenance and repair. To determine how this promising laser would perform under high pressure in-situ conditions, GTI performed a number of experiments with results directly comparable to previous data. Experiments were designed to investigate the effect of laser input parameters on representative reservoir rock types of sandstone and limestone. The focus of the experiments was on completion and perforation applications, although the results and techniques apply to well construction and other rock cutting applications. All previous laser/rock interaction tests were performed on samples in the lab at atmospheric pressure. To determine the effect of downhole pressure conditions, a sophisticated tri-axial cell was designed and tested. For the first time, Berea sandstone, limestone and clad core samples were lased under various combinations of confining, axial and pore pressures. Composite core samples consisted of steel cemented to rock in an effort to represent material penetrated in a cased hole. The results of this experiment will assist in the development of a downhole laser perforation prototype tool. In the past, several combinations of laser and rock variables were investigated at standard conditions and reported in the literature. More recent experiments determined the technical feasibility of laser perforation on multiple samples of rock, cement and steel. The fiber laser was capable of penetrating these materials under a variety of conditions, to an appropriate depth, and with reasonable energy requirements. It was determined that fiber lasers are capable of cutting rock without causing damage to flow properties. Furthermore, the laser perforation resulted in permeability improvements on the exposed rock surface. This report discusses the design and development of a customized laser pressure cell; experimental design and procedures, and the resulting data on pressure-charged samples exposed to the laser beam. An analysis provides the resulting effect of downhole pressure conditions on the laser/rock interaction process.

Brian C. Gahan; Samih Batarseh

2005-09-28T23:59:59.000Z

413

Preliminary Drill Sites  

SciTech Connect

Preliminary locations for intermediate depth temperature gradient holes and/or resource confirmation wells based on compilation of geological, geophysical and geochemical data prior to carrying out the DOE-funded reflection seismic survey.

Lane, Michael

2013-06-28T23:59:59.000Z

414

Preliminary Drill Sites  

DOE Data Explorer (OSTI)

Preliminary locations for intermediate depth temperature gradient holes and/or resource confirmation wells based on compilation of geological, geophysical and geochemical data prior to carrying out the DOE-funded reflection seismic survey.

Lane, Michael

415

Acoustic data transmission through a drill string  

DOE Patents (OSTI)

Acoustical signals are transmitted through a drill string by canceling upward moving acoustical noise and by preconditioning the data in recognition of the comb filter impedance characteristics of the drill string. 5 figs.

Drumheller, D.S.

1988-04-21T23:59:59.000Z

416

Downhole drilling network using burst modulation techniques  

DOE Patents (OSTI)

A downhole drilling system is disclosed in one aspect of the present invention as including a drill string and a transmission line integrated into the drill string. Multiple network nodes are installed at selected intervals along the drill string and are adapted to communicate with one another through the transmission line. In order to efficiently allocate the available bandwidth, the network nodes are configured to use any of numerous burst modulation techniques to transmit data.

Hall; David R. (Provo, UT), Fox; Joe (Spanish Fork, UT)

2007-04-03T23:59:59.000Z

417

Drilling Waste Management Technology Identification Module  

NLE Websites -- All DOE Office Websites (Extended Search)

you are in this section Technology Identification you are in this section Technology Identification Home » Technology Identification Drilling Waste Management Technology Identification Module The Technology Identification Module is an interactive tool for identifying appropriate drilling waste management strategies for a given well location and circumstances. The Technology Identification Module follows the philosophy of a waste management hierarchy. Waste management options with the lowest environmental impacts are encouraged ahead of those with more significant environmental impacts. The Technology Identification Module helps identify waste management options, but users should also consider their own site-specific costs and waste volumes. How it Works Users will be asked to answer a series of questions about the location of the well site, physical features of the site that may allow or inhibit the use of various options, whether the regulatory agency with jurisdiction allows or prohibits particular options, and whether cost or the user's company policy would preclude any options. Nearly all questions are set up for only "yes" or "no" responses. Depending on how the initial questions are answered, users will face from 15 to 35 total questions. Some of these can be answered immediately, while others may require some additional investigation of other portions of this web site or external information. Suitable options will be identified as users complete the questions, and users will be able to print out a summary of suitable options when the process is completed.

418

Rotating head for rotary drilling rigs  

SciTech Connect

A rotating head is claimed for a rotary drilling rig which is to be secured to the top of a well pipe having an inner rotating portion with an opening therethrough which permits passage of drill pipe, pipe joints, and Kelly tools; the rotating portion has an annular drive rubber formed integrally with the top portion thereof. A rotating head drive bushing having an opening with a cross-sectional shape generally conforming to the cross-section of the Kelly tool to permit only sliding motion therebetween is provided with helical external ridges which produce a disengagable gripping action with the opening in the drive rubber at the top of the rotating portion of the rotating head. The rotating portion has a conventional stripper rubber at the bottom thereof and is mounted with a double roller bearing to provide low friction motion with respect to the fixed portion of the head. The double roller bearing is lubricated with a viscous lubricating material and paddles are provided between the sets of rollers of the double roller bearing for distributing the viscous lubricating material and in particular propel it onto the upper set of bearings; the upper body portion of the rotating head is readily detachable from the lower sleeve portion which is normally welded to the well conductor pipe.

Adams, J.R.

1983-09-27T23:59:59.000Z

419

Advanced Drilling Systems for EGS  

Energy.gov (U.S. Department of Energy (DOE))

Project objectives: Apply Novateks Stinger® and JackBit® technology in the development of an innovative; durable fixed bladed bit and improved roller cone bit that will increase ROP by three times in drilling hard rock formations normally encountered in developing EGS resources.

420

GRR/Section 19-WA-f - Water Well NOI for Replacement or Additional Wells |  

Open Energy Info (EERE)

GRR/Section 19-WA-f - Water Well NOI for Replacement or Additional Wells GRR/Section 19-WA-f - Water Well NOI for Replacement or Additional Wells < GRR Jump to: navigation, search GRR-logo.png GEOTHERMAL REGULATORY ROADMAP Roadmap Home Roadmap Help List of Sections Section 19-WA-f - Water Well NOI for Replacement or Additional Wells 19-WA-f - Water Well NOI for Replacement or Additional Wells.pdf Click to View Fullscreen Contact Agencies Washington State Department of Ecology Regulations & Policies Revised Code of Washington 90.44.100 Revised Code of Washington 18.104.048 Washington Administrative Code 173-160-151 Triggers None specified A developer seeking to use ground water for an activity may need to drill a new well in a different location than a previous well, drill an additional well at an existing location, or drill a replacement well at the same

Note: This page contains sample records for the topic "horizontal wells drilling" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


421

Deep drilling data, Raft River geothermal area, Idaho-Raft River geothermal  

Open Energy Info (EERE)

Deep drilling data, Raft River geothermal area, Idaho-Raft River geothermal Deep drilling data, Raft River geothermal area, Idaho-Raft River geothermal exploration well sidetrack-C Jump to: navigation, search GEOTHERMAL ENERGYGeothermal Home Report: Deep drilling data, Raft River geothermal area, Idaho-Raft River geothermal exploration well sidetrack-C Details Activities (1) Areas (1) Regions (0) Abstract: Cassia County Idaho; data; geophysical surveys; Idaho; Raft River geothermal area; surveys; United States; USGS; Well No. 3; well-logging Author(s): Covington, H.R. Published: Open-File Report - U. S. Geological Survey, 1/1/1978 Document Number: Unavailable DOI: Unavailable Exploratory Well At Raft River Geothermal Area (1977) Raft River Geothermal Area Retrieved from "http://en.openei.org/w/index.php?title=Deep_drilling_data,_Raft_River_geothermal_area,_Idaho-Raft_River_geothermal_exploration_well_sidetrack-C&oldid=473365"

422

Slim hole drilling proven in remote exploration project  

SciTech Connect

This paper reports on a helicopter-supported slim hole exploration project in a remote tropical forest which cost 15% less than a conventional drilling operation. The potential savings after improvements in rig equipment, bits, and drilling and coring methods may approach 30%. Because of the small size of the slim hole equipment, the impact on the rain forest was small. The areas cleared for locations and access during the operation were 75% less than that required for similar operations with conventional road-transported rigs. During the second half of 1991, Total Exploration Gabon, a subsidiary of Total Exploration Production, conducted a slim hole drilling project in the Gabonese tropical rain forest in a joint venture with Chevron Corp., Exxon Corp., and Austria's OMV AG. During this helicopter-supported operation, two wells were drilled: one to 2,747 m (9,010 ft) ending with a 3 in. hole and one to 418 m (1,371 ft) ending with a 5-7/8 in. hole. Continuous coring operations recovered 1,868 m (6,127 ft), or 59% of the total length drilled.

Dachary, J. (Total Exploration Production, Libreville (GA)); Vighetto, R. (Total Exploration Production, Paris (FR))

1992-06-22T23:59:59.000Z

423

The Snake River Geothermal Drilling Project - Innovative Approaches to  

Open Energy Info (EERE)

Snake River Geothermal Drilling Project - Innovative Approaches to Snake River Geothermal Drilling Project - Innovative Approaches to Geothermal Exploration Geothermal Project Jump to: navigation, search Last modified on July 22, 2011. Project Title The Snake River Geothermal Drilling Project - Innovative Approaches to Geothermal Exploration Project Type / Topic 1 Recovery Act: Geothermal Technologies Program Project Type / Topic 2 Validation of Innovative Exploration Technologies Project Description This project will implement and test a series of innovative geothermal exploration strategies in two phases. Phase 1 studies will comprise surface mapping, shallow seismic surveys, potential field surveys (gravity and magnetics), compilation of existing well data, and the construction of three dimension structure sections. Phase 2 will comprise two intermediate depth (1.5-1.6 km) slim-hole exploration wells with a full suite of geophysical borehole logs and a vertical seismic profile to extrapolate stratigraphy encountered in the well into the surrounding terrain. Both of the exploration wells will be fully cored to preserve a complete record of the volcanic stratigraphy that can be used in complementary science projects. This project will function in tandem with Project Hotspot, a continental scientific drilling project that focuses on the origin and evolution of the Yellowstone hotspot.

424

DIRECTIONAL PROPAGATION CANCELLATION FOR ACOUSTIC COMMUNICATION ALONG THE DRILL STRING  

E-Print Network (OSTI)

The success in finding the oil reserves depends, in part, on real-time (while-drilling) information acquired of oil reserves in the formation. Cur- rently, two telemetry methods are used: wireline telemetry and mud.gardner@halliburton.com ABSTRACT A new telemetry method in oil well services uses compres- sional acoustic waves to transmit data

425

Tight gas sands study breaks down drilling and completion costs  

SciTech Connect

Given the high cost to drill and complete tight gas sand wells, advances in drilling and completion technology that result in even modest cost savings to the producer have the potential to generate tremendous savings for the natural gas industry. The Gas Research Institute sponsored a study to evaluate drilling and completion costs in selected tight gas sands. The objective of the study was to identify major expenditures associated with tight gas sand development and determine their relative significance. A substantial sample of well cost data was collected for the study. Individual well cost data were collected from nearly 300 wells in three major tight gas sand formations: the Cotton Valley sand in East Texas, the Frontier sand in Wyoming, and the Wilcox sand in South Texas. The data were collected and organized by cost category for each formation. After the information was input into a data base, a simple statistical analysis was performed. The statistical analysis identified data discrepancies that were then resolved, and it helped allow conclusions to be drawn regarding drilling and completion costs in these tight sand formations. Results are presented.

Brunsman, B. (Gas Research Inst., Chicago, IL (United States)); Saunders, B. (S.A. Holditch Associates Inc., College Station, TX (United States))

1994-06-06T23:59:59.000Z

426

Step-Out Drilling Results at Blue Mountain, Nevada | Open Energy  

Open Energy Info (EERE)

Step-Out Drilling Results at Blue Mountain, Nevada Step-Out Drilling Results at Blue Mountain, Nevada Jump to: navigation, search OpenEI Reference LibraryAdd to library Journal Article: Step-Out Drilling Results at Blue Mountain, Nevada Abstract Step-out drilling targets based on a detailed structural model at Blue Mt. Nevada have led to high permeability entries in a well offset 1.2 km west of the developing field at Blue Mountain,Nevada. This well, 58-15, targeted shallow and deep entries based on a model with faults in the hanging wall and in the underlying range front fault zone. Drilling results showed that both zones were permeable. The deep target showed up in several productive fractures at relatively high temperatures. This result supports the general conceptual model of upflow from depth on Piedmont faults. The purpose of

427

Alphine 1/Federal: Drilling report. Final report, Part 1  

SciTech Connect

Regional geologic and geophysical surveys, shallow temperature-gradient drilling, and published reconnaissance geothermal studies infer possible hot dry rock (HDR) geothermal resources in the Alpine-Springerville area. This report discusses the results of a State of Arizona and US Department of Energy funded drilling project designed to gather the deep temperature and stratigraphic data necessary to determine if near-term HDR geothermal potential actually exists in this portion of the White Mountains region of Arizona. A 4505 feet deep slim-hole exploratory well, Alpiner/Federal, was drilled within the Apache-Sitgreaves National Forest at Alpine Divide near the Alpine Divide Camp Ground about 5 miles north of Alpine, Arizona in Apache County (Figure 1).

Witcher, J.C. [New Mexico State Univ., Las Cruces, NM (United States). Southwest Technology Development Inst.; Pisto, L. [Tonto Drilling Services, Inc., Salt Lake City, UT (United States); Hahman, W.R. [Hahman (W. Richard), Las Cruces, NM (United States); Swanberg, C.A. [Swanberg (Chandler A.), Phoenix, AZ (United States)

1994-06-01T23:59:59.000Z

428

Drilling problems don't slow Williston basin operators  

SciTech Connect

In spite of the Williston basin's tough drilling environment, exploration activity has continued to increase, especially around northwestern North Dakota's Nesson anticline. The foremost drilling problem is the Charles slat section, which lies 8000-9000 ft deep; this section requires a salt-saturated mud system with additives, a heavyweight pipe, and a careful cementing job. Nevertheless, big discoveries - such as Texaco Inc.'s gas well in McKenzie Co., which tested at 9.9 million CF/day and 179 bbl/day of condensate - will spur exploration for some time since most of the basin remains untouched. Moreover, drilling engineers will soon be able to mitigate, if not eliminate, the typical difficulties encountered.

Moore, S.D.

1982-01-01T23:59:59.000Z

429

Final report on the design and development of a Rolling Float Meter for drilling-fluid outflow measurement  

SciTech Connect

Lost circulation, which is the loss of well drilling fluids to the formation while drilling, is a common problem encountered while drilling geothermal wells. The rapid detection of the loss of well drilling fluids is critical to the successful and cost-effective treatment of the wellbore to stop or minimize lost circulation. Sandia National Laboratories has developed an instrument to accurately measure the outflow rate of drilling fluids while drilling. This instrument, the Rolling Float Meter, has been under development at Sandia since 1991 and is now available for utilization by interested industry users. This report documents recent Rolling Float Meter design upgrades resulting from field testing and industry input, the effects of ongoing testing and evaluation both in the laboratory and in the field, and the final design package that is available to transfer this technology to industry users.

Staller, G.E.; Westmoreland, J.J.; Whitlow, G.L.; Wright, E.K.; Glowka, D.A.

1998-03-01T23:59:59.000Z

430

GRR/Section 19-WA-e - Water Well Notice of Intent for New Well | Open  

Open Energy Info (EERE)

GRR/Section 19-WA-e - Water Well Notice of Intent for New Well GRR/Section 19-WA-e - Water Well Notice of Intent for New Well < GRR Jump to: navigation, search GRR-logo.png GEOTHERMAL REGULATORY ROADMAP Roadmap Home Roadmap Help List of Sections Section 19-WA-e - Water Well Notice of Intent for New Well 19-WA-e - Water Well Notice of Intent for New Well.pdf Click to View Fullscreen Contact Agencies Washington State Department of Ecology Regulations & Policies Revised Code of Washington 18.104.048 Washington Administrative Code 173-160-151 Triggers None specified A developer seeking to use ground water for an activity may need to drill a new well to access the ground water. When a developer needs to drill a new well, the developer must complete the Notice of Intent (NOI) to Drill a Well form and submit the form to the Washington State Department of Ecology

431

Top drive drilling systems  

SciTech Connect

This patent describes a well apparatus which consists of: a back-up tool for holding the upper end of a string of pipe against rotating as an additional section of pipe is connected thereto; and powered means for moving the tool to engage the upper end of the string: the powered means being operable through a predetermined range of movement, and acting to move the back-up tool vertically during an initial portion of the range of movement and then move the tool between an active position at the axis of the well and a retracted position offset to a side of the axis at the end of the range of movement.

Boyadjieff, G.I.

1986-08-12T23:59:59.000Z

432

Borehole Data Package for One CY 2005 CERCLA Well 699-S20-E10, 300-FF-5 Operable Unit, Hanford Site, Washington  

SciTech Connect

This report supplies the information obtained during drilling, characterization, and installation of the new groundwater monitoring well. This document also provides a compilation of hydrogeologic and well construction information obtained during drilling, well development, and sample collection/analysis activities.

Williams, Bruce A.; Bjornstad, Bruce N.; Lanigan, David C.; Keller, Jason M.; Rockhold, Mark L.

2006-03-29T23:59:59.000Z

433

Definition: Stepout-Deepening Wells | Open Energy Information  

Open Energy Info (EERE)

Stepout-Deepening Wells Stepout-Deepening Wells Jump to: navigation, search Dictionary.png Stepout-Deepening Wells A well drilled at a later time over remote, undeveloped portions of a partially developed continuous reservoir rock. A deepening well is reentering a well and drilling to a deeper reservoir. Often referred to as an "infield exploration well" in the oil and gas industry.[1] Also Known As delayed development well References ↑ http://www.answers.com/topic/step-out-well Ste LikeLike UnlikeLike You like this.Sign Up to see what your friends like. p-out-well: a well drilled in the expected extent of a reservoir that is being developed but at a significant distance, usually two or more drilling and spacing units, from the nearest producer in that reservoir. A step-out

434

An approach for assessing engineering risk from shale gas wells in the United States  

Science Journals Connector (OSTI)

Abstract In response to a series of “energy crises” in the 1970s, the United States government began investigating the potential of unconventional, domestic sources of energy to offset imported oil. Hydraulic fracturing applied to vertical tight sand and coal bed methane wells achieved some degree of success during a period of high energy prices in the early 1980s, but shale gas remained largely untapped until the late 1990s with the application of directional drilling, a mature technology adapted from deepwater offshore platforms that allowed horizontal wells to penetrate kilometers of organic-rich shale, and staged hydraulic fracturing, which created high permeability flowpaths from the horizontal wells into a much greater volume of the target formations than previous completion methods. These new engineering techniques opened up vast unconventional natural gas and oil reserves, but also raised concerns about potential environmental impacts. These include short-term and long-term impacts to air and water quality from rig operations, potential migration of gas, fluids and chemicals through the ground, and effects on small watersheds and landscapes from roads, pads and other surface structures. Engineering risk assessment commonly uses integrated assessment models (IAMs), which define sources of risk from features, events and processes. The risk from each system element is assessed using high-fidelity models. Output from these is simplified into reduced-order models, so that a large, integrated site performance assessment can be run using the IAM. The technique has been applied to engineered systems in geologic settings for sequestering carbon dioxide, and it is also applicable to shale gas, albeit with some modifications of the various system elements. Preliminary findings indicate that shale gas well drilling and hydraulic fracturing techniques are generally safe when properly applied. Incident reports recorded by state environmental agencies suggest that human error resulting from the disregard of prescribed practices is the greatest cause of environmental incidents. This can only be addressed through education, regulations and enforcement.

Daniel J. Soeder; Shikha Sharma; Natalie Pekney; Leslie Hopkinson; Robert Dilmore; Barbara Kutchko; Brian Stewart; Kimberly Carter; Alexandra Hakala; Rosemary Capo

2014-01-01T23:59:59.000Z

435

Optical coherence tomography guided dental drill  

DOE Patents (OSTI)

A dental drill that has one or multiple single mode fibers that can be used to image in the vicinity of the drill tip. It is valuable to image below the surface being drilled to minimize damage to vital or normal tissue. Identifying the boundary between decayed and normal enamel (or dentine) would reduce the removal of viable tissue, and identifying the nerve before getting too close with the drill could prevent nerve damage. By surrounding a drill with several optical fibers that can be used by an optical coherence domain reflectometry (OCDR) to image several millimeters ahead of the ablation surface will lead to a new and improved dental treatment device.

DaSilva, Luiz B. (Danville, CA); Colston, Jr., Bill W. (Livermore, CA); James, Dale L. (Tracy, CA)

2002-01-01T23:59:59.000Z

436

Chemical Speciation of Chromium in Drilling Muds  

SciTech Connect

Drilling muds are made of bentonite and other clays, and/or polymers, mixed with water to the desired viscosity. Without the drilling muds, corporations could not drill for oil and gas and we would have hardly any of the fuels and lubricants considered essential for modern industrial civilization. There are hundreds of drilling muds used and some kinds of drilling muds contain chromium. The chemical states of chromium in muds have been studied carefully due to concerns about the environmental influence. However it is difficult to determine the chemical state of chromium in drilling muds directly by conventional analytical methods. We have studied the chemical form of chromium in drilling muds by using a laboratory XAFS system and a synchrotron facility.

Taguchi, Takeyoshi [X-ray Research Laboratory, RIGAKU Corporation, 3-9-12 Matsubara-cho, Akishima-shi, Tokyo 196-8666 (Japan); Yoshii, Mitsuru [Mud Technical Center, Telnite Co., Ltd., 1-2-14 Ohama, Sakata-shi, Yamagata 998-0064 (Japan); Shinoda, Kohzo [Institute of Multidisciplinary Research for Advanced Materials, Tohoku University, 2-1-1 Katahira, Aoba-ku, Sendai-shi, Miyagi 980-8577 (Japan)

2007-02-02T23:59:59.000Z

437

:- : DRILLING URANIUM BILLETS ON A  

Office of Legacy Management (LM)

'Xxy";^ ...... ' '. .- -- Metals, Ceramics, and Materials. : . - ,.. ; - . _ : , , ' z . , -, .- . >. ; . .. :- : DRILLING URANIUM BILLETS ON A .-... r .. .. i ' LEBLOND-CARLSTEDT RAPID BORER 4 r . _.i'- ' ...... ' -'".. :-'' ,' :... : , '.- ' ;BY R.' J. ' ANSEN .AEC RESEARCH AND DEVELOPMENT REPORT PERSONAL PROPERTY OF J. F. Schlltz .:- DECLASSIFIED - PER AUTHORITY OF (DAlE) (NhTI L (DATE)UE) FEED MATERIALS PRODUCTION CENTER NATIONAL LFE A COMPANY OF OHIO 26 1 3967 3035406 NLCO - 886 Metals, Ceramics and Materials (TID-4500, 22nd Ed.) DRILLING URANIUM BILLETS ON A LEBLOND-CARLSTEDT RAPID BORER By R. J. Jansen* TECHNICAL DIVISION NATIONAL LEAD COMPANY OF OHIO Date of Issuance: September 13, 1963 Approved By: Approved By: Technical Director Head, Metallurgical Department *Mr. Jansen is presently

438

Salton Sea Scientific Drilling Project: A summary of drilling and engineering activities and scientific results. Final report  

SciTech Connect

The Salton Sea Scientific g Project (SSSDP) completed the first major well in the United States Continental Scientific Drilling Program. The well (State 2-14) was drilled to 10,W ft (3,220 m) in the Salton Sea Geothermal Field in California`s Imperial Valley, to permit scientific study of a deep, high-temperature portion of an active geothermal system. The program was designed to investigate, through drilling and testing, the subsurface thermal, chemical, and mineralogical environments of this geothermal area. Extensive samples and data, including cores, cuttings, geothermal fluids and gases, and geophysical logs, were collected for future scientific analysis, interpretation, and publication. Short duration flow tests were conducted on reservoirs at a depth of approximately 6,120 ft (1,865 m) and at 10,136 ft (3,089 m). This report summarizes all major activities of the SSSDP, from project inception in the fall of 1984 through brine-pond cleanup and site restoration, ending in February 1989. This report presents a balanced summary of drilling, coring, logging, and flow-test operations, and a brief summary of technical and scientific results. Frequent reference is made to original records, data, and publication of results. The report also reviews the proposed versus the final well design, and operational summaries, such as the bit record, the casing and cementing program, and the coring program. Summaries are and the results of three flow tests. Several teamed during the project.

Ross, H.P.; Forsgren, C.K. [eds.

1992-04-01T23:59:59.000Z

439

Horizontal interest in industrial purchasing  

Science Journals Connector (OSTI)

Markets are becoming very complex and dynamic and in such an environment, firms can no longer merely focus their attention on key relationships in their downstream and upstream markets, but instead need to constantly monitor and make sense of the market around them. One area within these markets, that has been rather neglected within the current purchasing research are the other buyers in the market. The purpose of the present study is to examine the forms of horizontal interest in purchasing. The paper aims to answer the question: What are the forms of horizontal interest and how can these be incorporated into the functions of industrial purchasing? The paper applies theoretical knowledge and reports on an empirical case study conducted to address the question. As a result, a two-dimensional typology of the forms of horizontal interest and implications for industrial purchasing are presented.

Pauliina Ulkuniemi

2012-01-01T23:59:59.000Z

440

Nuclear component horizontal seismic restraint  

DOE Patents (OSTI)

A nuclear component horizontal seismic restraint. Small gaps limit horizontal displacement of components during a seismic occurrence and therefore reduce dynamic loadings on the free lower end. The reactor vessel and reactor guard vessel use thicker section roll-forged rings welded between the vessel straight shell sections and the bottom hemispherical head sections. The inside of the reactor guard vessel ring forging contains local vertical dovetail slots and upper ledge pockets to mount and retain field fitted and installed blocks. As an option, the horizontal displacement of the reactor vessel core support cone can be limited by including shop fitted/installed local blocks in opposing alignment with the reactor vessel forged ring. Beams embedded in the wall of the reactor building protrude into apertures in the thermal insulation shell adjacent the reactor guard vessel ring and have motion limit blocks attached thereto to provide to a predetermined clearance between the blocks and reactor guard vessel ring.

Snyder, Glenn J. (Lynchburg, VA)

1988-01-01T23:59:59.000Z

Note: This page contains sample records for the topic "horizontal wells drilling" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


441

Drill rig hook  

SciTech Connect

A hook for suspending a pipe string or other load in a well rig, including a tubular outer body supported by a first connector structure which is attachable to a suspending line, a tubular inner body which supports a second connector structure preferably taking the form of a hook, with the inner body being received within the outer body and being yieldingly urged upwardly relative thereto by a resilient unit or assembly located within the inner body, and with a structure within the inner body bearing upwardly against and supporting the resilient assembly and attached to the first connector structure. A cam mechanism between the inner and outer bodies automatically cams the inner body to a predetermined rotary position upon upward movement, with a locking device or devices serving to retain the inner body in fixed rotary position and/or to lock the camming mechanism in a fixed position in a manner determining the rotary setting to which the inner body returns upon upward movement. The mentioned first and/or second connectors may each consist of two parts receivable within one of the tubular bodies and held in operative connecting engagement therewith by a spacer between the two parts. A link suporting member may be formed separately from the load suporting hook, to be detachable therefrom for a repair or replacement.

Zimmermann, A.

1985-02-12T23:59:59.000Z

442

IDWS Form 4003-1, Application for Permit to Drill for Geothermal...  

Open Energy Info (EERE)

to be submitted to the office of the IDWS Director prior to the drilling of geothermal wells. Last revised January, 2011. Published NA Year Signed or Took Effect 2011 Legal...

443

An advanced geothermal drilling system: Component options and limitations  

SciTech Connect

The historical developments of drilling technology for geothermal resources have followed traditional incremental trends. The local expertise and rigs were adapted from existing drill rigs used for mining, civil, and water well projects. In areas with hydrocarbon resources, petroleum drilling hardware has been adapted; and in other countries, these units were imported as depth requirements increased and more robust derricks and downhole tools were needed. This ad hoc approach has provided adequate exploration and production wells. In contrast to the incremental improvements in petroleum rotary drilling system components this paper reviews a new, purpose-developed system that would solve the known major problems by design. Performance goals of 4 km (12,000 ft.) depth, 400 C, (750 F) and penetration rates greater than 8 m/h (25 ft/h) were selected. This advanced system was reviewed extensively and estimates of perhaps 30 to 60% cost savings were projected, depending on the assumed effectiveness and performance improvements provided. This paper continues the design and feasibility study and presents some of the component and sub-system details developed thus far.

Rowley, J. [Pajarito Enterprises, Los Alamos, NM (United States); Saito, Seiji [JMC Geothermal Division, Tokyo (Japan); Long, R.C. [Department of Energy, Las Vegas, NV (United States). Yucca Mountain Site Characterization Project

1995-12-31T23:59:59.000Z

444

Stimulation Technologies for Deep Well Completions  

SciTech Connect

The Department of Energy (DOE) is sponsoring the Deep Trek Program targeted at improving the economics of drilling and completing deep gas wells. Under the DOE program, Pinnacle Technologies conducted a study to evaluate the stimulation of deep wells. The objective of the project was to review U.S. deep well drilling and stimulation activity, review rock mechanics and fracture growth in deep, high-pressure/temperature wells and evaluate stimulation technology in several key deep plays. This report documents results from this project.

Stephen Wolhart

2005-06-30T23:59:59.000Z

445

Calculator program aids well cost management  

SciTech Connect

A TI-59 calculator program designed to track well costs on daily and weekly bases can dramatically facilitate the task of monitoring well expenses. The program computes the day total, cumulative total, cumulative item-row totals, and day-week total. For carrying these costs throughout the drilling project, magnetic cards can store the individual and total cumulative well expenses.

Doyle, C.J.

1982-01-18T23:59:59.000Z

446

Well record | OpenEI  

Open Energy Info (EERE)

Well record Well record Dataset Summary Description This dataset contains oil and gas drilling and permit records for February 2011. State oil and gas boards and commissions make oil and gas data and information open to the public. To view the full range of data contained at the Alaska Oil and Gas Conservation Commission, visit http://doa.alaska.gov/ogc/ Source Alaska Oil and Gas Conservation Commission Date Released February 28th, 2011 (3 years ago) Date Updated Unknown Keywords Alaska Commission gas oil Well record Data application/vnd.ms-excel icon http://doa.alaska.gov/ogc/drilling/dindex.html (xls, 34.3 KiB) Quality Metrics Level of Review Some Review Comment Temporal and Spatial Coverage Frequency Monthly Time Period License License Open Data Commons Public Domain Dedication and Licence (PDDL)

447