bluuebunny/crossref_metadata_2025_split huggingface dataset:
Drilling and Completion Strategies in Naturally Fractured Reservoirs
Authors: Ehlig-Economides C. A. , Taha Mohamed , Marin H. D. , Novoa Enrique , Sanchez O. 
Published: December 2007

Abstract
Traditional exploration drilling practices include targeting the structural crest; maintaining a vertical borehole; and drilling over-balanced for safety reasons. All three drilling practices may threaten success in naturally fractured reservoirs in which well and reservoir flow performance relies on flow through natural fractures. Depending on the deformation mechanism of folds, more folding related natural fractures may develop on the limb of the structure than on the crest. At typical depths, open fractures planes are likely to have a subvertical orientation; and a deviated borehole, drilled in a direction normal to the natural fractures, will intersect many more fractures than a vertical one. Over-balanced drilling can result in lost circulation of damaging drilling fluids and solids in the natural fractures. Cementing the fractured zones can further plug natural fractures, leaving little behind pipe to provide sought-after productivity from the natural fractures. This paper offers insight on drilling and completion strategies based on experiences in two South American locations with distinct structural styles. One is a Devonian gas discovery in Bolivia and the other a block southwest of Lake Maracaibo with both mature fields and exploration prospects of Cretaceous age. In both instances, the structural style and orientation provide a framework for borehole trajectory planning.
Introduction To Carbon Logging
Authors: McWhirter Vernie C. 
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.
This paper was prepared for the Improved Oil Recovery Symposium of the Society of Petroleum Engineers of AIME, to be held in Tulsa, Okla., March 22–24, 1976. Permission to copy is restricted to an abstract of not more than 300 words. Illustrations may not be copied. The abstract should contain conspicuous acknowledgment of where and by whom the paper is presented. Publication elsewhere after publication in the JOURNAL OF PETROLEUM TECHNOLOGY or the SOCIETY OF PETROLEUM ENGINEERS JOURNAL is usually granted upon request to the Editor of the appropriate journal provided agreement to give proper credit is made.
Discussion of this paper is invited. Three copies of any discussion should be sent to the Society of Petroleum Engineers office. Such discussion may be presented at the above meeting and with the paper, may be considered for publication in one of the two SPE magazines.

Abstract
A nuclear logging method to determine the presence of hydrocarbons behind casing regardless of water salinity has been developed.
This log, referred to (is the Carbon Log or Carbon/Oxygen Ratio Log, is commercially available on a limited basis in the United States and Canada..
For most of us in the oil production industry, the Carbon Log principle, including the technique, terminology and method of operation, is new. This paper is written and presented for those who desire an introduction to Carbon Logging.
The intent of this paper is to cover the basic nuclear principles involved, instrument operation and how use is made of the nuclear reactions.
Examples of interpretation techniques for the determination of oil saturation, lithology, salinity and the presence of gas are shown.

Introduction
The nuclear reactions from which the Carbon Log measurements are obtained are not new. Reactions that occur when certain elements are bombarded with high energy neutrons are well documented.
Fortunately, a number of the elements that are present in the rock matrix and the fluid contained therein do react in some identifiable way to neutron bombardment.
The Carbon Log is made possible due to the fact that Dresser Atlas has a monoenergetic neutron source that can be controled so as to provide a desired amount of neutrons in periodic bursts, i.e. the neutrons produced are of one specific energy level---14.2MEV.
Application And Selection Of Electric Submergible Pumps
Authors: O'Neil Richard K. 
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.
This paper was prepared for the Improved Oil Recovery Symposium of the Society of Petroleum Engineers of AIME, to be held in Tulsa, Okla., March 22–24, 1976. Permission to copy is restricted to an abstract of not more than 300 words. Illustrations may not be copied. The abstract should contain conspicuous acknowledgment of where and by whom the paper is presented. Publication elsewhere after publication in the JOURNAL OF PETROLEUM TECHNOLOGY or the SOCIETY OF PETROLEUM ENGINEERS JOURNAL is usually granted upon request to the Editor of the appropriate journal provided agreement to give proper credit is made.
Discussion of this paper is invited. Three copies of any discussion should be sent to the Society of Petroleum Engineers office. Such discussion may be presented at the above meeting and with the paper, may be considered for publication in one of the two SPE magazines.

Introduction
This paper reviews the application of electric submergible pumping systems to oil field pumping requirements. Also presented is a typical pump and motor design procedure and a review of operating parameters that can affect pump performance.

DESCRIPTION OF EQUIPMENT
The submergible pumping system's major components are motor, protector, pump and cable which are run into the well on tubing. Surface components are the cable junction box, switchboard and transformers. Figure 1 shows the downhole equipment.

Motor
The submergible electric motor is a 3-phase, induction type, that is oil-filled for cooling and lubrication. A high starting torque enables it to reach full load operating speed of approximately 3500 RPM in less than fifteen cycles, thus reducing drag on the power supply. Cooling is achieved by heat transfer to the well fluid moving by the motor. For this reason, the unit is set above the producing zone. Submergible motors have been successfully operated in ambient temperatures in excess of 300 deg.. These motors are available in a range of diameters, horsepowers and voltages to accommodate a wide variety of applications.
Preventive Maintenance for Beam Pumping Equipment
Authors: Bullard Denny B. 
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.
This paper was prepared for the Improved Oil Recovery Symposium of the Society of Petroleum Engineers of AIME, to be held in Tulsa, Okla., March 22–24, 1976. Permission to copy is restricted to an abstract of not more than 300 words. Illustrations may not be copied. The abstract should contain conspicuous acknowledgment of where and by whom the paper is presented. Publication elsewhere after publication in the JOURNAL OF PETROLEUM TECHNOLOGY or the SOCIETY OF PETROLEUM ENGINEERS JOURNAL is usually granted upon request to the Editor of the appropriate journal provided agreement to give proper credit is made.
Discussion of this paper is invited. Three copies of any discussion should be sent to the Society of Petroleum Engineers office. Such discussion may be presented at the above meeting and with the paper, may be considered for publication in one of the two SPE magazines.

Introduction
A preventive maintenance (PM) program has been established in the southeastern New Mexico portion of Continental Oil Co.'s production department operation. The PM system has been in operation for 12 months and covers over 2,000 separate pieces of major surface equipment.
The concept of preventive maintenance is not new in production operations; however, most operating organizations incorporate PM and operations in one organization. The primary disadvantage of this type of set-up is the secondary priority PM receives. Day-today operating problems normally receive first priority and PM work is done after "emergencies" are handled. For that reason, Conoco's "PM" organization has been separated from the "operations" organization.
Preventive maintenance is the systematic inspection, cleaning, lubrication, and servicing of equipment. The objective of PM is to prevent malfunctions and breakdowns, with the result that all mechanical equipment will work as well and as long as it should with minimum repairs.
Operations include those tasks that have to be done to efficiently produce oil and gas wells, to monitor and control oil-field facilities, to answer alarms, and to assure that environmental and safety standards are maintained. An efficient production operation must give equal priority to operational tasks and PM.
This paper deals only with the PM for beam pumping equipment. However, the procedures followed in establishing the PM for the beam pumping equipment are essentially the same for all pieces of equipment included in this project.

PM ORGANIZATION
The PM work for all of the equipment covered is under the direction of a PM foreman. Four two-man crews and a test engineer are assigned to the PM production foreman. Two of these crews handle PM on waterflood equipment; one crew is assigned tank battery equipment; and pumping units are serviced by the fourth two-man team. The test engineer uses specialty test equipment such as vibration analyzers on all equipment in the field.
Each PM team also handles "breakdown" repair work to the equipment assigned to them.
Deepwater Riser Management
Authors: Cummins I , Neme E , Todd W 
Published: December 2007

Abstract
This paper discusses how it is both cost effective and operationally practical to use a fitness for purpose approach to riser inspection scheduling instead of a technique based on accumulated fatigue damage within each riser joint. At the same time, the inherent scheduling uncertainties are reduced.
The riser monitoring that is necessary for successful operation of a deepwater riser and for inspection scheduling is also outlined. A calibration technique is evolved for the predicted riser inspection scheduling and safety is improved by providing early warning of an accumulation of unexpectedly high fatigue damage with an effective monitoring system.
Significant time and cost savings can be made while maintaining high levels of safety with these practical solutions, which could contribute to the development of an industry standard.
Case Histories of Design and Implementation of Underbalanced Wells
Authors: Giffin David R. , Lyons William C. 
Published: December 2007

Abstract
As operators strive to increase production from existing reservoirs with depleted reservoir pressure, the use of underbalanced drilling and underbalanced horizontal drilling is becoming more widely used. One of the primary problems to overcome in drilling under-balanced is designing a circulating "fluid" that has an equivalent circulating density below the reservoir pressure. This paper discusses the mathematical equations used to design air drilled "under-balanced" wells. It will also show how these equations were used to design four separate wells. The presentation of actual field data will validate these equations and computer modeling used. (See Table 1) The four wells will include 1) 17,000 TVD well drilled into the Ellenberger formation with reservoir pressure at 1200 psig, 2) horizontal well drilled into the Petit formation at 5900 ft. TVD with reservoir pressure at 210 psig, 3) horizontal wells drilled into the upper Penn Formation at TVD 7800 ft. and reservoir pressure of 1000 psig., and 4) deviated wells drilled into the Ellenberger formation below 13,000 feet TVD and reservoir pressure of 600 psig.
The mathematical equations used were developed by Dr. William C. Lyons of New Mexico Institute of Mining and Technology in Socorro, NM. Computer simulations for these wells were run by David Giffin on software developed by Boyum Guo and Dr. Lyons. Each of these wells was drilled using air drilling techniques. By measuring the pressure at both surface and bottom hole conditions, the validity of the mathematical models used has been established. Air or other compressed gas can be used to reduce equivalent circulating densities to accommodate almost any reservoir pressure.
Casing Drilling Application Design Considerations
Authors: Warren Tommy M. , Angman Per , Houtchens Bruce 
Published: December 2007

Abstract
Casing Drilling is an emerging technology for simultaneously drilling and casing a well where the casing is used to transmit mechanical and hydraulic energy to the bit, instead of using a conventional drill-string. A drilling assembly, positioned in the lower end of the casing, replaces the tools normally located on the lower end of the conventional drill-string. This assembly is retrieved with a wireline to access bits, motors, underreamers, MWD/LWD, and other components while leaving the casing in place.
The Casing Drilling process has been used on portions of ten wells during a field trial phase. The system is still undergoing development but these wells have demonstrated the functionality of the casing drilling system.
A New Borehole Surveying Technique for Horizontal Drilling Processes Using One Fiber Optic Gyroscope and Three Accelerometers
Authors: Noureldin A. , Tabler H. , Irvine-Halliday D. , Mintchev M. P. 
Published: December 2007

Abstract
Current borehole surveying techniques during horizontal drilling processes utilize three-axis magnetometers and three-axis accelerometers inside the Measurement-While-Drilling (MWD) assembly. The measurements received from the three accelerometers are processed to provide the tool face angle (roll) and the deviation angle from the vertical direction (pitch). The magnetometers measure the magnetic field in three mutually orthogonal directions to provide the ongoing azimuth. Due to the massive amount of steel around the drilling rig, the magnetometers are installed inside costly non-magnetic drill collars. Moreover, the deviation of the Earth's magnetic field from ore deposits reduces the accuracy of any downhole magnetic field based measurements. The fiber optic gyroscope (FOG) currently employed in different navigation applications can be adapted for the borehole surveying. A previous feasibility study showed that the FOG has excellent immunity to the severe downhole environment. The objective of this article is to develop a new navigation algorithm utilizing the FOG mounted on the horizontal plane of the borehole assembly together with three orthogonal accelerometers. The mechanization equations necessary to process the measurements from the FOG and the three accelerometers and deliver the drill bit attitude (azimuth, pitch and roll) as well as its coordinates (latitude, longitude and depth) are provided. The accuracy of the applied algorithm was found to be about 99 %. In addition, applied optimal estimation techniques based on Kalman filter algorithms are presented to compensate for the measurement errors from the FOG and the accelerometers.
A Proven Liner Flotation Method for Extended-Reach Wells
Authors: Trahan Kevin , MacDonald Jamie , Webster Steve , Mason Colin 
Published: December 2007

Abstract
Based on a case history, this paper introduces a complete field-proven solution to running and cementing a liner into a world-record extended-reach well.
Flotation was used to assist in getting the liner to depth. Although floating a liner into a well is not a new concept, this case was unique, because flotation was achieved by using only standard Weatherford liner tools, with no need for special, possibly unproven, flotation devices. Weatherford also supplied unique friction-reducing devices that allowed for rotation of the liner during cementing operations.
Personnel performed extensive modeling and profile work before proceeding with operations at the well site. The preliminary modeling work revealed that, if the liner were run conventionally, the weight of the liner could create a significant friction force on the open-hole section that could prevent the liner from reaching the required setting depth. Ultimately, if corrective techniques were not applied, the liner could no longer be run into the hole, because set-down weight was limited to the block weight of the drilling rig.
In this case, the strategy was to float the entire length of the liner to minimize drag in the open-hole section, keep the drillpipe full of mud, and push the liner to the required depth.
A Stick-slip Analysis Based on Rock/Bit Interaction: Theoretical and Experimental Contribution
Authors: Challamel N. , Sellami H. , Chenevez E. , Gossuin L. 
Published: December 2007

Abstract
The purpose of this paper is to analysis bit stick-slip motion by using rock mechanics considerations coupled with field bottomhole data.
The data was collected using an instrumented PDC bit. This new tool enables to measure accelerations, Weight-On-Bit (WOB) and Torque-On-Bit (TOB) directly above the bit. Tests were conducted in Montrose (Scotland) at about 700 m depth in a consolidated Devonien sandstone. During several hours of testing, the sensitivity to operating and different structural parameters was evaluated. The effect of stick-slip on Rate Of Penetration (ROP) was quantified: ROP is really affected by this dynamical phenomenon which appears above a certain Weight-On-Bit threshold.
Two stages rule the drillstring behaviour. The stationary behaviour (small oscillation of the rotation bit speed around the mean value) is described by modal analysis. Experimental frequencies are in agreement with the theoretical natural ones. A perturbation of the operating parameters (generally an increasing of the WOB) makes the system bifurc towards stick-slip. The dynamical system is now governed by a non linear autonomous boundary condition, linked to the rock/bit interaction. Rock mechanics considerations justifie such a law. Numerical simulations converge on stick-slip, typical limit cycle experimentally exhibited.
The last analysis is focused on an analysis of "drill-off test". In this operating stage, the rock/bit interaction function changes. Numerical simulations, justified by clearly experimental evidence, show the benefit effect of such a test, which stabilizes the system. A discussion on the effect of the stabilizers and bit type follows as well as how to attenuate this non linear phenomenon.
Method of Rapid Stabilizing Shut-In Drillipipe Pressures for Blowout Wells
Authors: Li Xiangfang , Gang Tao , Sui Xiuxiang 
Published: December 2007

Abstract
A new well control method is proposed to shorten the drillpipe pressure stabilized time after shut-in. Long stabilized period is extremely harmful to well control, especially for unstable well-hore, pipe will probably be stuck due to the long shut-in time. Our new method is proved simple, practical and robust from the test results of computer simulation, physical model in full scale and application on site. It provides a new way of well control. The process of pressure buildup after shut-in is now under control. The stabilized time is shortened and the influx of invaded reservoir fluid is decreased greatly. Thus the well control becomes easy.
In our new method, using a mud or cementing pump, intermittently a certain amount of drilling mud is pumped into wellhore at a small flowing rate, resulting in the desired initial shut-in drillpipe pressure. Wild cat well, exploration well and development well are required a different initial shut-in drillpipe pressure. In terms of the pressure buildup after the first batch of drilling mud, The next pumping time and mud volume to be pumped are determined by the computer model. Our study set up the mathematical model to determine the desired initial shut-in drillpipe pressure through pumping and the computer program is coded for application on site.
Heavy-Oil Production Enhancement by Encouraging Sand Production
Authors: Dusseault Maurice B. , El-Sayed Samir 
Published: December 2007

Abstract
Dramatic increases in oil production rates have been achieved in many Canadian heavy oil reservoirs. These reservoirs are 30% porosity unconsolidated sandstones with oil ranging from 500 to 12,000 cP viscosity. Furthermore, many of these reservoirs have proven to be almost impossible to exploit economically with horizontal wells or with thermal processes.
After reviewing the mechanics of CHOP (Cold Heavy Oil Production), the production history of the Luseland Field in Saskatchewan is reviewed. This is almost a unique case history because conventional production, horizontal wells, and CHOP have all been attempted in a small geographic area. Encouraging sanding resulted in over a four-fold increase in oil production rate and a total extraction ratio now just in excess of 11% overall. An aggressive CHOP program implemented after many years of conventional production and after a six-well horizontal production program achieved this increase. Conventional production was marginally economic, but the horizontal wells were failures.
Several other case histories are summarized to demonstrate that CHOP wells in these reservoirs are usually just as productive as much more costly horizontal wells.
We believe that CHOP technology is a far better option than thermal stimulation or horizontal wells in many cases where the reservoir state and rock properties are suitable.
Improved Oil Recovery in Carmópolis Field: R&D and Field Implementations
Authors: Mezzomo Roberto F. , Luvizotto José M. , Palagi Cesar L. 
Published: December 2007

Abstract
Carmópolis Field in Sergipe/Alagoas Basin in northeastern Brazil is the country's largest onshore oil accumulation at 253 MMm3OOIP and a current total oil production of 2,880 m3/d. Discovered in 1963, it was quickly put into primary production. Waterflooding followed in 1971 at the central portion of the field. The combination of adverse fluid mobility ratio, reservoir heterogeneity and the lack of proper selective injection, led to the quick decline of production. Immediately, a major program of selective plugging, stimulation and selective injection was able to stabilize production. Waterflooding was then extended to the entire main block of the field. Well pattern was changed from five to nine-spot arrangement, with a corresponding downsizing in well spacing and injection rates. Carmópolis has also experienced several pilot projects for Enhanced Oil Recovery (EOR): polymer flooding, steamflooding and in situ combustion, respectively.
This past history of Carmópolis Field and the significance of waterflooding to oil production in Brazil with approximately 1,850 MMm3OOIP currently submitted to this method of recovery, led to the selection of Carmópolis as the target for one of the projects in the portfolio of PRAVAP - Petrobras Strategic Improved Oil Recovery (IOR) Program. The scope of this project included the review of the waterflooding operation through improved reservoir characterization and flow simulation, as well as the investigation of other IOR methods that might reverse the production declining trend. This paper summarizes the outcome of this project that went from lab research to field testing and led to the approval of operational implementations worth US$ 34 million NPV.