bluuebunny/crossref_metadata_2025_split huggingface dataset:
Field Experience Using Drilling Cost Minimization Programs
Authors: Wood W.D. 
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.

Abstract
Application of computer-calculated drilling cost minimization has been successful in the exploratory floating-rig drilling of the 9/13 block in the United Kingdom sector of the North Sea. Applications will continue with the drilling of future wells from the "A" platform.

Introduction
Drilling Cost Minimization, Optimum Drilling, OP Drilling and other similar terms have been used for computer-calculated, programmed drilling simulation for several programmed drilling simulation for several years. Speer in 1959 was one of the first to publish a concept of how to calculate cost-minimizing drilling programmes. Galle and Woods detailed programmes. Galle and Woods detailed technical procedures in 1960. By 1964 Edwards was advocating "drill on paper" to reduce drilling costs. Most of the major oil companies since then have used, in varying degrees, some form of calculated cost minimization programme in their drilling efforts.
Lummus presented a description of Amoco's efforts for drilling in the North Sea.
Various optimizing methods have been described; optimization by bit run, by interval or by well, have all been tried. Several methods were described in one recent paper. The use of the computer for paper. The use of the computer for calculating many alternatives and determining the optimum conditions is now routine. Several service organisations offer digital data-gathering equipment, on-site computers and foot-by-foot formation evaluations.
This paper will describe Mobil North Sea Limited's application of computer-calculated simulated drilling for the 9/13 block in the United Kingdom sector of the North Sea.

Background
In 1972 Mobil drilled the first well in the 9/13 block in the United Kingdom sector of the North Sea. With no wells within one hundred miles, this was a rank wildcat and no effort was made towards a calculated optimization program.
A 4-Year Experience With Dynamically Positioned Drilling Vessels
Authors: Vasseur B. 
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.

Abstract
Three dynamically positioned drilling vessels have now been in operation during several years to fulfill offshore petroleum exploration tasks on a worldwide basis.
Among them are the sisterships "PELICAN" and "HAVDRILL" aboard which the drilling management is provided by FORAMER S.A. of Sevres, France. These are the only two units which have been originally built without any conventional mooring system nor any re-entry guide lines.
Both units have accumulated a combined four-year experience in widely scattered areas ranging from Labrador to Angola. A very large number of data covering the floater behaviour and the resulting operational efficiencies have been gathered and analyzed. They include the environmental conditions; their influence on the unit motions and the positioning over the drilling well; the consequences for the actual activity; the various operational procedures; the economical factors and the procedures; the economical factors and the resulting ability to predict and prepare future tasks.
On the basis of this information it has also been possible to improve the design of future PELICAN-type units capable of drilling in much greater water depths (three are now being built under FORAMER engineering) and to extend the same concept to larger ships and other types of floating units.
The existing dynamically positioned vessels have now fully proved the reliability of anchorless drilling units by safely and efficiently completing their assignments - among which the successful "PELICAN" campaign offshore Labrador during the summer of 1973 has been the most significant demonstration to the entire petroleum exploration industry.
An Overview of the IADC Deepwater Well Control Guidelines
Authors: Christman S. , Kelly A. , Plaisance M. , Kropla S. , Metcalf J. , Robinson E. , Weddle C. 
Published: December 2007

Abstract
In response to technical challenges unique to deepwater drilling and production operations, a Task Force comprised of representatives from major and independent operators, drilling contractors, academia, well-control experts and equipment manufacturers has developed the IADC Deepwater Well Control Guidelines for industry wide circulation. Problem prevention is the emphasis of the Guidelines, which includes chapters on the five key issues identified by participants: Well Planning; Well Control Procedures; Equipment; Emergency Response; and Training. The result is a compilation of the industry's existing best practices, covering considerations and procedures from some of the best people in the industry. Developing the Guidelines within a one-year timeframe with a minimal budget was accomplished through the dedication of committee members, the support of their companies, and use of the Internet to facilitate peer review.
When "No" is the Appropriate Answer to the Customer
Authors: de Wardt J. P. , Leggett D. M. 
Published: December 2007

Abstract
The traditional method of establishing relationships between customers and suppliers in the drilling business is very inefficient and wastes money through consuming resources without adding value. Some new processes have been introduced but low bid is still often the primary determinate of success. These will be reviewed, the issues still to be addressed identified and solutions discussed. Two avenues of improvement will be described: 1) suppliers evaluating their opportunity and declining where appropriate; 2) customers removing cumbersome systems from the past and using new, more intelligent and efficient methods for selecting suppliers.
When saying "no" is the right answer.
Pursuing unsuccessful bids is both a waste of direct effort and a dilution of resources, which could be properly assigned to developing potentially successful opportunities. The current personnel constraints on the drilling business make this intolerable for companies who wish to differentiate themselves. These companies will adopt logical processes to select the bid opportunities they will pursue. These processes will include strategy development with a clear understanding of target markets, business plans which specify prioritization through cost / benefit ratios and decisions trees which consistently lead contractors / suppliers to the highest potential opportunities. Suppliers will ultimately say "no" to the customer when clearly indicated through their decision processes, in a manner that enhances the relationship.
Creating value adding supplier selection processes.
Customers in other industries have gained significant productivity improvements through early selection and alignment of suppliers. Methods exist to quickly assess the real value that can be delivered and to make early selections. Price of the contract can be balanced with the value delivered by the supplier to achieve a true evaluation. Suppliers are integrated into the planning process for maximum benefit and parallel engineering dramatically cuts cycle time and development costs. A far more effective supplier selection method than the current practice will be described which will reduce the expected rise in "no bids".
Improvements in the bidding process will lead to improvement in achieving well objectives through faster cycle times, increased value and more consistent achievement of objectives. A necessary requirement in the current low oil price environment.
Evolution of Well Design in the Campos Basin Deepwater
Authors: Saliés J. B. , Nogueira E. F. , Evandro T. M. F. 
Published: December 2007

Abstract
This paper presents the evolution of well design at the Campos Basin to meet the new challenges of deeper and deeper waters. It discusses how well design has evolved from six casing strings to only three because of the peculiar geological characteristics of deep waters, and technological advances. The main aspects this paper takes in consideration are the evolution of well programs and wellhead systems. It also offers a new integrated approach for drilling, production, and intervention and discusses some of the results. Among other conclusions, we argue that the evolution of well design together with technological advances are key factors in deepwater exploration.
Casing Drilling – A Revolutionary Approach to Reducing Well Costs
Authors: Tessari R. M. (Bob) , Madell Garret 
Published: December 2007

Abstract
Rotary drilling, as we know it today, replaced percussion or cable tool drilling in the 1930's. Since that time, wells have been drilled using a drill string consisting of drill pipe, drill collars, a bit and varying downhole tools known as a "bottom hole assembly" (BHA). When the bit wears out or the BHA has to be changed, the process of "tripping" is commenced. Tripping consists of hoisting the drill string out of the well in lengths of 30, 60, or 90 feet. This process is labour, equipment and energy intensive and takes up to 35% of the total time to drill a well. In addition to the productive drilling time lost to tripping, unscheduled events during tripping can make the drilling process even more inefficient and even lead to losing the well. This paper describes the process of a threeyear research and development project to develop and commercialize casing drilling. Casing drilling will use standard oilfield casing to both drill and simultaneously case the well. Bottom hole assemblies will be retrieved on wire line up the inside of the casing. Casing drilling will eliminate the use of drill pipe, significantly reduce tripping times and reduce time lost due to unscheduled events such as reaming, fishing and taking kicks while tripping (See Fig. #1). This paper describes the tools to be used, including a special purpose built drilling rig for this process. The anticipated results of drilling with casing are discussed and specific conclusions include up to 30% savings in well costs feasible through drilling with casing.
Down-Hole Simulation Cell for Measurement of Lubricity and Differential Pressure Sticking
Authors: Isambourg P. , Ottesen S. , Benaissa S. , Marti J. 
Published: December 2007

Abstract
The impact of lubricity and differential sticking on well cost is becoming more important, due to activity increase in deviated and extended reach wells through depleted reservoirs. Drilling fluid characteristics play a major role in this area. A better understanding of the mechanism of differential sticking and proper evaluation of the lubricating characteristics of different drilling fluid systems, under simulated down-hole conditions, is becoming more important. A specially designed fully automated device permits accurate and reproducible measurements of coefficient of friction between metal and mud filter cake. It also monitors the variation of the filter cake pore pressure and permeability, corresponding forces and sticking time. Testing principle is based on cylindrical captor equipped with sensors (rotational for lubricity and non-rotational with axial motion for differential sticking test). Displacement into the cylindrical filter cake is made automatically through lateral motion of a measurement cell that can be rotated 360 degrees. The main advantage of this apparatus is the fact that the pressure and force sensors are located inside the cell, allowing for direct measurements. Evaluation of both water and oil based fluids differential sticking potential can be achieved, and data generated can be a useful tool to take corrective measures in selecting a suitable stable drilling fluid/additives, that will help prevent differential sticking and reduce torque and drag. A series of differential pressure sticking tests have been conducted. Data generated were used to understand the phenomenon, to characterize the risk of differential pressure sticking associated with drilling fluids, and, also, will be used to further validate numerical models. This paper describes specifications and measurement principle of this special equipment, as well as first results on differential pressure sticking tests.
Successful Use of the Hydraulic Workover Unit Method for Underbalanced Drilling
Authors: Robichaux D. 
Published: December 2007

Abstract
This paper describes two very successful underbalanced drilling operations that were performed in Belgium and in the coastal area of The Netherlands. The underbalanced drilling operations used a hydraulic workover (HWO) unit to effectively control the well pressure during drilling. This method is unique because it reduces damage to the formation and causes very little environmental risk.
For the Belgian operation, drilling was preceded by a series of tests and simulations. A hydraulic workover data acquisition system was installed to provide the highest possible control of the drilling process. A 9 5/8" shoe was drilled, and a cement bond log was run, after which injectivity tests were performed at the shoe. A bottom hole assembly (BHA) with an 8 ½" bit was then used to drill into the reservoir at which point the well was predicted to go underbalance with fresh water as the drilling fluids. Although the well did not flow, the underbalance drilling systems ran flawlessly and the BHA was retrieved without any problems. The well was then cased with 7" liner.
The second case history represents one of the most complex and technically challenging underbalance drilling projects to date due to the offshore environmentally sensitive location in the North Sea and the high BHP of 250 bar. The same steps of preparation as the prior well were gone through but this time the client required a zero discharge of gasses or fluids. Some of the precautions taken consisted of console enclosures, hose covers, drip pans and the entire hydraulic workover unit had to be encapsulated. The target fault was crossed successfully while meeting all of the strict environmental restrictions and client objectives.
The success of the method must also be attributed to the operational planning and close attention paid to experience gained from previous drilling operations from the multidisciplined crews. The execution of the treatment utilized all of the components considered to be state-of-the-art in drilling including the use of a data acquisition system, real-time treatment pressure monitoring and HWO drilling procedures applied.
Pressured Mud Cap Drilling: Efficient Drilling of High-Pressure Fractured Reservoirs
Authors: Urselmann R. , Cummins J. , Worrall R. N. , House G. 
Published: December 2007

Abstract
Drilling sour, high-pressure fractured reservoirs can involve complex, unpredictable, and hazardous well control situations. Using Pressured Mud Cap Drilling, Shell Venezuela S.A. have drilled a sour, high pressure, proof of concept well in an offshore fractured carbonate reservoir. This paper briefly overviews the evolution of this technique.
Full-scale Experimental Study for Improved Understanding of Transient Phenomena in Underbalanced Drilling Operations
Authors: Lage A. C. V. M. , Nakagawa E. Y. , Time R. W. , Vefring E. H. , Rommetveit R. 
Published: December 2007

Abstract
A dynamic computer simulator for underbalanced drilling can contribute significantly for designing an UBD operation and defining the most appropriate operational procedures. Timing for flow stabilization, pressure peaks in the returns and pressure variations at the bottom of the well are some of the aspects involved in determining the adequate injection flow rates, separation system and drilling procedures.
A full-scale experimental investigation was planned and executed to provide data for the evaluation and improvement of transient underbalanced drilling computer simulators. The tests were performed in a 1278 m vertical well in a research facility in Brazil. The experiments involved the injection of liquid and gas through a 3 1/2" drill-string (ID=2.992") and the return of the mixture via the annulus between the drill-string and a 7" casing (ID=6.366").
First, a pulse consisting of a gas-liquid mixture with high velocity was injected. The available data acquisition system in the research facility kept track of the whole evolution of the gas distribution inside the drill-string and through the annulus. A sequence of two gas pulses was pumped and analyzed as well.
These tests revealed some important aspects about the flow behavior: how gas spreads along flow direction and gas rise velocities. This information gives support for the perfecting gas rise velocity model and the numerical schemes used to solve the conservation equations.
A New International Standard for Casing/Tubing Connection Testing
Authors: Payne M. L. , Schwind B. E. 
Published: December 2007

Abstract
This paper presents background on and an overview of a new International Standard for casing/tubing connection testing. This new standard is a recommended practice and has been developed with broad international input via an ISO Work Group that has been active in recent years. Industry experiences from previous public and proprietary connection test procedures have been studied and the lessons learned have been incorporated into this new standard. Adoption of the new standard by E&P operators world-wide is recommended and will carry substantial benefits. These benefits include elimination of connections in the market place with inadequate qualification testing, documentation of manufacturer-rated connection integrity including combined loads, and stringent yet cost-effective qualification tests to evaluate connection ratings. Industry trends towards more efficient pipe design methods, such as probabilistic methods, make connection rating and qualification more crucial than in years past. Attaining these objectives will enable higher reliability in the industry's drilling and completion programs. Simultaneously, more cost effective wells will result from objective data on the performance of casing and tubing connections.
Field Evaluation of Corrosion Control Chemicals in the Viking Gas Field
Authors: King W.R. , Taylor F.R. 
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.
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
Corrosion inhibitors were field tested to find a chemical which, using methanol as a carrier, gave the best performance in three types of well completion. Inhibitor performance was evaluated on the basis of performance was evaluated on the basis of corrosion protection, low toxic transfer to the effluent water and lack of emulsion forming tendencies.

Introduction
The Viking Gas Field, 86 miles East of Mablethorpe, Lincolnshire, England was discovered in 1968 by Conoco and the National Coal Board (Exploration) Limited, at approximately 9,000 ft subsea in the Rotliegend sandstone. Two main reservoirs Viking 'A' and Viking 'B' as well as a series of smaller satellite structures are linked by a pipeline system to an onshore gas dehydration pipeline system to an onshore gas dehydration plant at Mablethorpe (Figure 1). plant at Mablethorpe (Figure 1).The produced gas contains 0.3–0.35 Mol % of CO2, no detectable H2S and is fully saturated with water vapour under wellhead flowing conditions. As the partial pressure of CO2 is in the range where corrosion is probable, chemical-injection facilities for each probable, chemical-injection facilities for each well were provided in the original process design.
No gas dehydration is carried out offshore except for the removal of free water condensed in process equipment as a result of pressure and temperature drops. The gas flowing from the wells is first passed to a wellhead separator for initial passed to a wellhead separator for initial removal of liquids (condensate/water) and then to a flow control valve at which the gas pressure is reduced to pipeline entrance conditions (+ 1450 psig). Secondary liquid removal takes place, after this pressure drop, in pipeline scrubbers before the gas passes directly to the main 28" pipeline to shore.
The liquids removed at the wellhead separators and at the pipeline scrubbers are passed to a three phase separator operating passed to a three phase separator operating at 400 psig. The condensate from the three phase separator is passed to one side of an phase separator is passed to one side of an atmospheric surge tank and then pumped back into the pipeline to shore. Water from the three phase separator is further treated for condensate removal on the other side of the surge tank before passing for final condensate removal to a utility sump with a sea leg. Provision is also made to route all liquids directly to the pipeline to shore, bypassing the liquid handling facilities.
Level 5 Multilateral Completed on Alaska's North Slope: A Case History
Authors: Isaacson William S. , Seale Rocky 
Published: December 2007

Abstract
Recent advances in multilateral technology have broadened the perspective of both re-entry and grass root wells. New tool designs, procedures, and completion equipment allow increased possibilities and functionality of multilateral wells. Multiple reservoir penetrations of a single or several reservoirs are possible from one well. Injection or production can be controlled in each leg of the well by means of downhole chokes or independent production strings. Advantages of this technology include, reduced surface footprint in environmentally sensitive or space confined areas, lower capital expenditures on surface facilities and existing wellbore infrastructure, and elimination of drilling new wells through potentially hazardous formations.
In late 1995 ARCO Alaska, Inc. began to evaluate multilateral technology and its application for adding value in the Kuparuk River Field on the North Slope of Alaska. The incentive for bringing multilateral technology to Kuparuk was access to smaller pockets of reserves, not economically recoverable at new well costs. This paper provides an in depth review of the first level 5 multilateral well constructed on the North Slope. Discussed are characteristics of a level 5 multilateral and the reasons this wellbore configuration was needed in Kuparuk. The discussion portrays equipment and procedures developed to accomplish well construction and provides a detailed review of the actual operations, with lessons learned during the process.