bluuebunny/crossref_metadata_2025_split huggingface dataset:
First Successful Multilateral Well Installation From a Floating Rig: Development and Case History
Authors: Freeman Austin , Gronas Tore , Berge Frode , Durst Doug , Luke Mike 
Published: December 2007

Abstract
This paper details the design, development, testing, and installation of the first successful multilateral well installed from a floating rig offshore Norway. Well design constraints were evaluated with respect to their impact on a multilateral well. These constraints included rig heave affecting multilateral operations, horizontal junction placement, unconsolidated junction/reservoir rock, and requirements for a cemented junction. Potential problems were determined, and materials and processes were developed to provide resolutions for these problems. Testing was performed to verify that the solutions planned would be successful. New developments for the project included a rate-of-penetration controller tool and a new fluid-loss-control device. Other firsts included the use of a single hollow whipstock to mill the casing window as well as treatment of the junction area with a consolidating chemical to improve stability and reduce the tendency for sand production.
The multilateral well was constructed according to plan with no serious problems and is currently producing from both laterals.
P. 647
Studies Dispel Myths, Give Guidance on Formulation of Drilling Fluids for Shale Stability
Authors: Simpson J.P. , Walker T.O. , Aslakson J.K. 
Published: December 2007

Abstract
Shale instability problems when using water-base drilling fluids have remained unresolved for decades because of a lack of knowledge and understanding of the shale hydration mechanisms. The industry has relied upon hydrocarbon-base drilling fluids for combating shale problems, but misconceptions have kept even those fluids from being utilized to their fullest advantage. With the use of hydrocarbon-base fluids now being curtailed because of environmental concerns, costs due to shale problems could escalate.
The understanding of shale instability problems has been hindered by inadequate laboratory means of simulating contact of drilling fluid and shale under downhole conditions of stress and temperature. To address this situation Gas Research Institute has conducted a project in which laboratory equipment and procedures were developed to permit preserved specimens of downhole shale (cored in hydrocarbon-base mud) to be restored to in situ axial stress, horizontal stress, pore pressure and temperature prior to being drilled at a selected borehole pressure. Provisions were made for measurement of fluid transport in either direction between the circulating drilling fluid and the shale during an extended period of exposure. The borehole pressure was then reduced incrementally to observe for borehole failure and obtain a measure of effect of the drilling fluid on the relative stability of the shale.
The above procedures have been used to study a well- known troublesome Cretaceous shale cored using oil-base mud at a depth of about 5,500 ft in Block 4 of the U.K. sector of the North Sea. This paper presents data showing that the aqueous activity of either a water-base or hydrocarbon-base emulsion drilling fluid can be adjusted to develop osmotic pressure that will cause water to enter or be extracted from a low-permeability shale. The hydraulic differential between the borehole pressure and far-field shale pore pressure is also shown to be a driving force affecting the transfer of water.
Discussion of these test results dispels several existing myths and provides guidelines for more effective use of current drilling fluids. The results also provide guidance for development of new environmentally acceptable water-base systems for combating shale problems where the use of hydrocarbon-base fluids is not permitted.
P. 731
Radio Communications in the Petroleum Industry
Authors: Stover Jerry S. 
Published: December 2007

Introduction
Communication is the nervous system of industry and it takes many forms. Letters, memos, telephone, telegraph, and personal conferences all play their important part in the control and direction of industrial operations. This is particularly true in petroleum operations where time is often of the essence. A paradox has existed, however, because in field operations, where time usually reaches its greatest value, the ability to communicate has often been severely restricted. The advent or practicable field radio communications has now provided this essential link in the communications chain. Because its application is so widespread, petroleum engineers may frequently be called upon to consult with the radio engineer in the design of a system for an oil company's particular operation. The petroleum engineer with a detailed knowledge of his company's operations, together with a working knowledge of radio can be of material assistance in the system design. The purpose of this paper is to provide the petroleum engineer with a general description of the various types of petroleum radio systems, capabilities, limitations, cost and operating features.

Drilling Operations
Radio communication was initially used in drilling operations shortly after World War II, when rugged FM (Frequency Modulation) equipment suitable for the severe operating conditions of drilling rig use was developed. The basic drilling rig system consists of a station installed on the drilling rig and a mobile station installed in the toolpusher's car. This provides communication with the rig at all times, enabling the pusher to contact the rig to see what supplies are needed before driving out from town. More important, the rig is able to contact him at any time.
Special extension control units can be plugged in so the toolpusher may receive and send messages from his bedside at night using the station in his car. Because the antenna of the drilling rig station is located atop the 120 ft derrick, this basic system, a rig unit and car unit, has an operating radius or approximately 35 miles, and costs approximately $1800.
Oil companies or drilling contractors that operate a number or rigs within a 60 to 100 mile radius of a field office frequently install stations at the office. Drilling reports, requests for supplies, orders, etc., can be transmitted directly between the office and rig at any time. If the office is closed at night, a remote control unit is often installed in one of the employee residences to permit handling of emergency night calls. An office station with an operating radius to drilling rigs of 50 to 60 miles costs approximately $1,000. A more powerful station, with high antenna for communication range up to 100 miles, costs $6,000 to $8,000.
Acoustiviewer - A New Method for Inspection of Down-Hole Tubular Goods
Authors: Schaller Herman E. , Kilpatrick Robert , Stratton Robert 
Published: December 2007

Abstract
Utilizing a down-hole acoustical scanning device, parted casing, split pipe, enlarged slots, holes and other abnormalities in pipe can be identified. The obvious importance of this information can be a controlling factor in remedial work. First, the precise location of the problem is identified in a relatively short time and recorded at the surface. Secondly, the scope of the problem is defined which enables the optimum planning for corrective action. To date the field results with this tool have been limited to the Los Angeles Basin.

INTRODUCTION
Sub-surface mechanical problems are inherent in the exploitation, development and production of oil reservoirs. Included in these problems are corroded pipe, partially collapsed pipe, split casing, parted or sheared casing, enlarged perforations. The severity of the damage may range from a potentially serious condition to one in which the well becomes completely ineffective. The latter condition has been experienced when sub-surface movement of strata occurred and in the Wilmington field has required special completion techniques to try and prevent reoccurrence of such casing failures.
In order to locate and attempt to identify the nature of down-hole mechanical failures it has been the practice to run feelers, impression blocks, caliper surveys, casing inspections, packers to pressure-test casing, impression packers and where conditions permit, photographic devices. Each of the above may be helpful in defining the problem but even a combination of several may still not provide the desired information.
In 1968, Mobil Research and Development Corp. announced a 'new and unique logging tool, called the Borehole Televiewer' to provide a means 'to inspect boreholes and to evaluate formations'.1 This new tool was 'primarily developed to evaluate fractured reservoirs . . .' 'The borehole can be filled with any homogenous gas-free liquid such as fresh water, saturated brine, crude oil or drilling muds. This tool takes an 'acoustic picture' of the borehole wall. The resulting log is a representation of the bore-hole wall as if it were split vertically and laid flat.' 'Any physical changes in the borehole wall are seen as changes in picture intensity. In this way, fractures, deformation or pits are reflected on the log.'1
Factors Affecting Foam Circulation in Oil Wells
Authors: Millhone Ralph S. , Haskin C.A. , Beyer A.H. 
Published: December 2007

This paper was prepared for presentation at the 47th Annual Fall Meeting of the Society of Petroleum Engineers held in San Antonio, Tex., Oct. 8–11, 1972. 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 who the paper is presented. Publication elsewhere after publication in the JOURNAL 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. 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
The utility of aqueous foams as circulating fluids in wells with low bottomhole pressure has been established. Although foams are simple to prepare, their behavior to changes in flow and well parameters is complex. The effects parameters is complex. The effects on foam flow of a number of these parameters were investigated by parameters were investigated by using a computerized mathematical model developed from newly reported research. Trends in job design factors such as injection pressure, bottomhole pressure, pressure, bottomhole pressure, circulation time and lifting ability are shown to be related to flow velocity and the liquid volume fraction of foam. A series of figures, some operating rules and a table summarizing directional trends of these design factors for a number of the more important flow and well parameters are presented. It is concluded that foam job design studies should be done when new lob objectives, well configurations or fields are encountered.

Introduction
The effectiveness and economic attractiveness of aqueous foam as a circulating fluid in well cleanout and drilling operations has been shown. Foam is increasingly important for a wide variety of oil field work where its low density and relatively high solids-lifting capability are needed. Foam has been successfully used in conventional and thru-tubing operations both onshore and offshore, in hard rock and soft sand provinces, and in permafrost areas. A vast amount of permafrost areas. A vast amount of experience with this unusual fluid is now commercially available from a number of service companies who have completed approximately two thousand foam circulation jobs.
Prediction of optimum gas and liquid rates, pressures, circulation time or solids-lifting ability is often difficult because of the complexity of foam circulation in wells.
Long Term Deliverability Forecasts for Dual Porosity Gas Reservoirs
Authors: Agarwal S.K. , Beveridge S.B. 
Published: December 2007

This paper was prepared for presentation at the 47th Annual Fall Meeting of the Society of Petroleum Engineers held in San Antonio, Tex., Oct. 8–11, 1972. 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 who the paper is presented. Publication elsewhere after publication in the JOURNAL 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. 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
It is well recognized that the field deliverability of dual porosity reservoirs does not follow the projections made using standard analytical or two dimensional modelling techniques. Although the literature reports a number of methods to analyze the pressure buildups for such reservoirs, these methods do not provide a means of computing long term deliverability.
This paper discusses the use of three dimensional modelling techniques to determine reserves and to project the deliverability of dual porosity gas reservoirs. The two field applications presented include:
a naturally fractured reservoir, and a reservoir where severe stratification makes it behave like two or more independent reservoirs communicating through shale-breaks or "windows" between them.
The pressure buildups recorded in these fields are unusual. Wells with core permeability of 20 to 40 md continue to buildup for more than fifteen months and exhibit an extraordinary rise near the end of the shut-in period. A history match using the above model resulted in the determination of the pore volume of each porosity system and the "flow capacity" between these systems. The model, for the prediction of deliverability, simultaneously solves the equations describing flux flow through the reservoir, the wellbores, the tubings and the surface system. Results show that the effect on deliverability of changes in the surface gathering system, number of wells or the operational strategy will be seriously miscalculated if the dual porosity effect is not considered.

Introduction
The ability to accurately forecast gas field deliverability under various operating conditions is a necessity for the optimum exploitation of any gas reservoir.
A Review of the Consolidation and Rebound Processes in One-Dimensional Porous Columns
Authors: Raghavan R. 
Published: December 2007

Discussion of this paper is invited. Three copies of any discussion should be sent to the Society of Petroleum Engineers Office. Such discussions 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 review of the progress made in the last 5years is presented. Modern methods of analysis as they relate to oilfield operations are examined. Darcy's law and its implication as related to a mobile matrix are examined. The specific problem considered is a one-dimensional shrinkage or expansion of a porous system to a step function change in pressure at the base of the column that may be considered to be either semi-infinite or finite.
The theory presented in the review includes general forms of formation conductivity and pressure and couples the movement of soil particles and the associated mass flow of liquid. It is shown that the latter effect is extremely important. Further, the differences between consolidation and rebound (imbibition)processes are examined.
It is shown that, even though a nonlinear equation results, analytical solutions exist for a class of problems. Illustrative examples are presented. The nonlinear equation has also been solved numerically and the solutions obtained have been correlated with constant property through a transformation that is similar to the real gas-pseudopressure.
The effects of the overburden and gravity are examined separately. One aspect of consolidation or rebound that has resulted inconsiderable confusion is the choice of coordinate system (moving or stationary) to develope the mathematical model. This aspect is also examined in detail in this review.

Introduction
For over 3 decades, subsidence of the land surface has attracted the serious attention of a large number of workers in a wide variety of disciplines. More recently, there has been an added attraction mainly due to the environmental awakening, for man's activities have begun to inadvertently produce effects of considerable magnitude and human consequence.
It is well known that a number of mechanisms operate whereby the land may collapse (see studies of Allen, wherein it is shown that the subsidence and compaction may be a result of a wide variety of disparate causes either natural or as a result of man'sactivities). Irrespective of the cause of the sinking of the land, mathematical models developed to understand and predict subsidence are based on the pioneering work of Terzaghi. Most of these analyses involve the basic assumptions of Terzaghils analysis, even though some of them do take into account the variation of permeability, compressibility, and the like.(See, for example, the papers by Biot and Davis and Raymond and texts by Jaeger and Wu.)
Alternate Injection of HPG and Water - A Two Well Pilot
Authors: Dyes A.B. , Bensimina A. , Ait Saadi A.M. , Khelil C. 
Published: December 2007

Abstract
Many areas of the Hassi Messaoud oil reservoir in Algeria are undergoing miscible displacement by high pressure gas injection. Because of extreme reservoir heterogeneity and the unfavorable mobility ratio of miscible displacement by gas injection, the sweep efficiency, particularly the vertical sweep, is poor. As a result a two well pilot operation was started in the field in late 1968 to:
study the improvement in the sweep which could be achieved by following a miscible high pressure gas front with the alternate injection of gas and water, and study the injectivities and gas-oil ratio control of the process.
Ways to improve the injectivities and any problems which arise after water breakthrough are also to be studied. The pilot is still in progress but results are now available on the sweep, injectivities, and gas-oil ratio control
Breakthrough of the gas front into the producer occurred after 6 months of producer occurred after 6 months of injection but the water-gas front has not yet broken through after 32 months of injection. The gas front achieved a 22% volumetric sweep at breakthrough. The water-gas front has not yet broken through and has achieved a volumetric sweep of at least 85%. These are to be compared to a volumetric sweep of 10% to 12% at gas breakthrough for-gas injection alone in other areas of the field.
Miscible displacement ahead of the water-gas front has been continued by the maintenance of a free gas band. The gas-oil ratio production after gas breakthrough has been held to only 10% above solution by controlling the ratio of gas to water injected per cycle. A cumulative injection ratio of gas to water within the reservoir of 1.1 to 1.2 gave the desired results. This was in agreement with the design based on relative permeability curves.
Alternate Paths to Oil and Gas Supply from Domestic Sources
Authors: Searl Milton F. 
Published: December 2007

This paper was prepared for the 47th Annual Fall Meeting of the Society of Petroleum Engineers of AIME, to be held in San, Antonio, Tex., Oct. 8–11, 1972 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 paper is presented. Publication elsewhere after publication in the JOURNAL OF PETROLEUM TECHNOLOGY or the SOCIETY OF PETROLEUM ENGINEERS JOURNAL is usually granted upon requested to the Editor of the appropriate journal, provided agreement to give proper credit is made. 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 discussions may be presented at the above meeting and, with the paper, may be considered for publication in one of the two SPE magazines.

Abstract
The energy supply pattern projected in the National Petroleum Council's Initial Appraisal has been widely accepted as a forecast of the future even though not so intended and even though it does not appear to be a highly probable case. Other policy and supply options exist, including the option of placing greater reliance on North American sources of supply and relying on market prices and perhaps expanded research and development to bring forth the necessary supply. Some of the alternatives to the Initial Appraisal supply pattern may be more cost efficient from a national standpoint.
The prevailing view of the nation's future energy supply appears to be essentially that presented in the National Petroleum Council (NPC) Initial appraisal Petroleum Council (NPC) Initial appraisal of the U. S. Energy Outlook. (1) It is unfortunately that this initial appraisal has been widely accepted as representing the future course of events. The report's projections do not appear to be inevitable projections do not appear to be inevitable or even highly probable. The somewhat uncritical acceptance of the Initial Appraisal projections as a forecast of the future by some members of the industry and others tends to obscure the possibility that the nation may have real choices in the matter of energy supply within the period to 1985 as well as beyond. Moreover, period to 1985 as well as beyond. Moreover, some of the choices may be more cost efficient from the nation's viewpoint than the alternative represented by the Initial Appraisal projections.
The NPC report itself recognizes that the price, cost, and other economic assumptions on which its projections are based are only a "status quo" reference set and not maximum likelihood estimates of future economic parameters.