bluuebunny/crossref_metadata_2025_split huggingface dataset:
What Strategy for a Technical Drilling Information System?
Authors: Dumont J. 
Published: December 2007

Abstract
Most of the companies spend considerable time and effort in developing, implementing an adequate Information Technology System. For all of them, the questions are always the same: What's the strategy and the what's method for implementation ?
This paper describes TOTAL's project team strategy for applying Computer Technology to Drilling/Completion operations and the rapid development and installation in the operating affiliates (subsidiaries) of the new drilling system adopted by TOTAL.
This new system based on TOTAL's world wide drilling environment is thoroughly described, The business requirement specifications and the development, based on TOTAL's valuable past experience and the use of new tools, concepts and procedures, are also discussed.
This paper gives the method and solution adopted regarding the platform, data system management, engineering software's and Information Technology Organisation.
Finally, the keys to successful implementation in the Paris Head Quarters (HQ) and in the subsidiaries are included.
An Interactive Drilling Simulator for Teaching and Research
Authors: Cooper George A , Cooper Alexander G , Bihn Gregory 
Published: December 2007

Abstract
An interactive program has been constructed that allows a student or engineer to simulate the drilling of an oil well, and to optimize the drilling process by comparing different drilling plans.
The program operates in a very user-friendly way, with emphasis on menu and button-driven commands. The simulator may be run either as a training program, with exercises that illustrate various features of the drilling process, as a game, in which a student is set a challenge to drill a well with minimum cost or time under constraints set by an instructor, or as a simulator of a real situation to investigate the merit of different drilling strategies.
It has three main parts, a Lithology Editor, a Settings Editor and the simulation program itself. The Lithology Editor allows the student, instructor or engineer to build a real or imaginary sequence of rock layers, each characterized by its mineralogy, drilling and log responses. The Settings Editor allows the definition of all the operational parameters, ranging from the drilling and wear rates of particular bits in specified rocks to the costs of different procedures. The simulator itself contains an algorithm that determines rate of penetration and rate of wear of the bit as drilling continues. It also determines whether the well kicks or fractures, and assigns various other "accident" conditions. During operation, a depth vs. time curve is displayed, together with a "mud log" showing the rock layers penetrated. If desired, the well may be "logged", casings may be set and pore and fracture pressure gradients may be displayed. During drilling, the total time and cost are shown, together with cost per foot in total and for the current bit run.
A demonstration version of the program is available on the World Wide Web at the Berkeley Petroleum Engineering Page. Its current address is: msel6.mse.berkeley.edu
Using MS Visual Basic to Write Engineering Applications
Authors: Torres Donaldo E. , Anders Joseph L. 
Published: December 2007

Abstract
Microsoft Visual Basic for Windows (VB) allows Engineers to develop engineering applications that run in the Windows environment. VB provides the engineer a programming tool to write simple programs quickly that meet their needs. It is relatively easy to learn and use. Development of a Windows-like user interface is easy to do and there is a growing base of users and add-in applications.
The technological advances that have allowed engineering workstations to convert from a mainframe environment to a stand alone PC connected to a network have also provided new programming tools. Modern programming languages allow the programmer to quickly design screen panels and easily reuse code. This paper discusses the features available in VB and provides several program examples. Example programs written using VB include gas and oil fluid correlations, interpolation software, gas well bottom hole pressure from surface conditions, volumetric reserve calculations, simple log analysis, water pattern analysis and bottom hole pressure analysis. These applications were developed with Visual Basic version 3.0 Professional.
Economics of Damage Removal and Production Enhancement
Authors: Daneshy Ali 
Published: December 2007

Abstract
Beyond the ongoing major structural changes and cost savings resulting from the industry focus on increasing operational efficiencies, better technology holds the key to future reductions in the production cost of oil and gas. Achieving optimum productivity is a major component of this technology.
In the past most of the technical and operational aspects of production enhancement were keyed towards making reservoirs economically viable. This limited the application of such operations mostly to low permeability reservoirs, or when there was a drastic reduction in production rates. With the real price of oil steadily declining this need is continually extending towards higher permeabilities.
With focus on getting best return on investment it is no more enough to just be profitable. Optimum well productivity will enhance the economic value of any reservoir!! This paper will examine the economic impact of damage removal and production enhancement on reservoirs generally viewed to be high permeability.
Productivity Improvement by Frontier Horizontal Drilling in Italy
Authors: Schenato Adelmo 
Published: December 2007

Abstract
Italian domestic activity on horizontal wells has been specially addressed to carbonate reservoir and specifically targeted to re-entry in existing wells.
The speech will focus on the specific experience matured in frontier applications in Italy, from 1989 with the short radius drain holes in Sicily, throughout world record deep water short radius in the southern part of Adriatic sea and depth world record medium radius in a HP/HT reservoir in the Po Valley.
Production results will be reported as well as the achieved technological aspects.
Market Outlook For Athabasca Bitumen--The Economics of Location
Authors: Anderson B. S. , Chambers J. I. , McMurray D. R. 
Published: December 2007

Abstract
In situ bitumen production in the Athabasca Oil Sands Area in Northern Alberta, Canada, is well-positioned to make inroads into traditional markets for Canadian crude oil in Canada and in particular in the U.S. The development of the steam assisted gravity drainage (SAGD) technology has lowered supply costs and has made Athabasca bitumen competitive with other North American supply sources of heavy crudes and bitumens.
As part of a larger SAGD commercialization study, this paper examines potential markets for Athabasca bitumen, determines transportation options and costs to markets, and determines bitumen netback prices at the Athabasca Oil Sands Area resulting from sales to various markets.
The paper also examines how the current lack of pipeline infrastructure, out of the Athabasca Oil Sands Area, limits the market opportunity of Athabasca bitumen.
Mapping Temperature with Geostatistics Can Help Identify Steam-Chest and Optimize Oil Production
Authors: Yang An-Ping 
Published: December 2007

Abstract
As oil fields are being developed under difficult economical conditions, it becomes a matter of survival to be able to produce more oil with lower cost. In thermal recovery, one of the most important issues is the efficient use of steam injection. Temperature wells are used to measure the reservoir temperature. Geostatistical tools can be applied to these measurements to map reservoir temperature in a cross-section view or as a threedimensional volume for different time. This can help identify the steam-chest or hot-water region. When sand-zones are mapped and combined with the temperature map, cold regions in the sands can be located. The results can be used to estimate how much heat is in the reservoir and how much oil is remaining and where.
Geostatistical mapping has two advantages over conventional mapping. One is the geological concept of spatial continuity. Spatial continuity may be different in form and different for different direction and location. This offers flexibility and higher accuracy in the results. The other advantage is that geostatistical mapping can honor statistical distribution of the data. For example in the case of temperature, the lowest temperature and the highest temperature are usually limited and geostatistical mapping can honor these limits. Because temperature observation wells are usually far apart, geostatistical mapping can making full use of all information available to produce the best possible map.
Examples from the Kern River Field in California show how geostatistical mapping can be easily applied. A computer software on the PC is sufficient to do the job without additional cost. The results help the engineer optimize the thermal recovery operation.
Reservoir Monitoring And Evaluating On PTT Barat-Laut Structure As Part Of Reservoir Management Process
Authors: Briantoro Cecep , Tangkalalo Darwin , Soewono Soewono 
Published: December 2007

Abstract
The two important things in Reservoir Management Process are monitoring and evaluating. This paper will describe application of both steps on PTT Barat-laut structure.
PTT Barat-laut is one of hydrocarbon producing structures in Pangkalansusu field. Study on this structure is performed through several technical approaches, which are continuous monitoring on production well performance, well testing analysis, and 3-D seismic interpretation, for reservoir modelling.
An unique phenomenon is shown by the result of Pressure Build Up test which has been taken from several wells, providing layer or fracture indication in reservoir of PTT Barat-laut structure.
The other monitoring that occurs from production performance shows an anomaly on its decline rate, reaching 85–95 %/well/year.
3-D Seismic analysis on this structure shows several anomalies on its lines. "High amplitude" characteristic anomalies on 860 and 910 zones (the productive zones) refer some faults presence, and very strong "bright spot" performances have provided an indication of hydrocarbon accumulation in this structure.
By utilizing the techniques above can be obtained a global illustration of reservoir and geological characteristics of the structure. Further more, they will provide more realistic development idea.
Carbon Isotope Characterization of Migrating Gas in the Heavy Oil Fields of Alberta, Canada
Authors: Rich K. , Muehlenbachs K. , Uhrich K. , Greenwood G. 
Published: December 2007

ABSTRACT
The development of Western Canada's oil and gas reservoirs has resulted in a proliferation of wells. Many of these wells exhibit gas migration to surface. This migration occurs at rates between 0.01 and 200 m3/day and is of obvious industrial and public concern. Thus far, attempts to eliminate gas migration have been expensive and relatively unsuccessful as the problem is not yet well understood. Identifying the origin of the gas will improve the economics and the effectiveness of remedial measures. The isotopic composition of gases can reveal their origin and help determine the source of the migrating gas.
Both the production horizon gases and the migrating gas in the Lindbergh-Lloydminster oil fields are predominantly (&gt;96%) methane with trace components of higher hydrocarbons. Despite the lack of chemical differentiation, the gases possess unique carbon isotopic signatures. The methane of the production gases is very depleted in 13C (δ13C(PDB) ≈ −68 ‰), indicative of a bacterial origin. The trace ethane, propane and butane components of the Manville Group production gases are relatively enriched in 13C (δ13C ≈ −27‰, −18‰ and −20‰, respectively), and often the partitioning of 13C/12C between propane and butane is reversed compared to that of thermogenic gas, possibly the result of extensive biodegradation of these higher hydrocarbons. The source of the gas associated with the heavy oil field of the Lindbergh and Lloydminster regions is predominantly bacteriogenic, variably mixed with biodegraded thermogenic gas. Wherever sampled, the migrating gas was tagged by a δ13C ≈ −44‰ ethane. Such a signature is seen in the gases of the overlying Upper Cretaceous strata. The isotopic data suggest that the migrating gas is sourced from the shallow Fish Scales, White Speckled and perhaps the Lea Park Formations. Remedial efforts should therefore concentrate on Fish Scales and Second White Speckled shales.
Horizontal Well Sand Cleanouts
Authors: Heinrichs B. D. , Dedora G. 
Published: December 2007

Abstract
This paper discusses sand problems occurring in Horizontal Wells located in NE Alberta and NW Saskatchewan, Western Canada. These wells are completed in the heavy oil sands at 450–750 m TVD. Typical completions utilize 0.625 mm (0.025 in.) slots in liners 500m to 1200m long. The average length is approximately 900m. Some of the horizontal wells were initially very prolific at oil rates up to 70 m3/day (450 bbl/day) with no indication of sand problems. As depletion occurred, most of the wells only experienced one incident of a sand-plugging problem requiring an expensive cleanout in the horizontal liner section. The wells required more than one sand cleanout in the build section of the intermediate casing but these were relatively inexpensive. Many innovative improvements, techniques and even complete systems designed specifically for horizontal sand cleanouts have been developed in just a few years.
Slim-Hole, High-Volume, PC Pump Development for 140 mm Cased Well Applications
Authors: Chachula R. C. , Anderson D. G. 
Published: December 2007

Abstract
The slim hole high volume progressive cavity pump project was initiated to demonstrate that such an artificial lift technology could work successfully in viscous sand-cut crude slant well pad type field applications. The basic concept was to develop an innovative cost effective PC pumping system for reduced diameter longstring cased (140 mm or 5,50″) wells that has the capability of pumping-off projected target rates at reduced RPM's. Ultimately, a reduction in capital and operating expenditures is achievable for existing and future developments through the improved technology.
The successful performance of the prototype installations prompted the design and drilling of four pad sites comprised of two, 16 well and two, 8 well pad configurations. The authors concluded that successful pump performance and efficiencies in pumping-off 12° API sand laden crude would be achievable at reduced speeds within 35–45° reduced diameter slant wells. The reduced stator OD combined with flush tubing directly above the PC pump prevented the occurrence of "sand-ins" between the tubing-annular area, thereby reduced the frequency of servicing wells.
The ability to reduce producing problems associated with initial high sand volumes have focused current field studies on developing correlations between anticipated sand cuts and varying fluid viscosity to surface torque and pumping speed required. PC pump developments are focused on improving pump life through improved elastomers and new pump designs. Knowledge gained from these studies will lead to successful slim hole performance and point the way to future innovative technical developments in the areas of rodless pumping systems, downhole oil/water separation and modified power transmission components.
This paper describes the evolution of the progressive cavity pump system in the development of the Mannville Formations in the Wainwright-Frog Lake fields. Modifications made to the equipment design and techniques to optimize pumping operations is discussed.
Eliminating Sucker Rod Couplings Can Reduce Progressing Cavity Pump Operating Costs
Authors: Wiltse D. J. , Weir B. A. 
Published: December 2007

Abstract
It is common knowledge that some of the obstacles that must be overcome to successfully operate Progressing Cavity Pumping (PCP) Systems are attributed to conventional sucker rod couplings and the upset area around them.
This paper addresses how the use of continuous sucker rod in PCP Systems can dramatically reduce the overall operating costs in high viscosity, heavy oil lifting applications, as well as, high water cut, high volume lifting applications.
Eliminating the conventional sucker rod couplings, and therefore the constricting annulus effect, will alter the pump requirement by decreasing the differential pressure the pump must overcome. Thereby decreasing the horsepower requirement and ultimately decreasing the power consumption.
In watering out pay zones, completed with 73 mm (2-7/8″) tubing, a 25.4 mm (1″) sucker rod string may be required to accommodate the extra torque associated with lifting higher volumes of fluid. 25.4 mm (1″) continuous sucker rod can contribute to additional cost savings by providing the additional torque carrying capacity without increasing the tubing size.
Through the use of independent software modeling a comparison of conventional sucker rods versus continuous sucker rod in PCP Systems will be presented to illustrate how operating cost reductions may be realized through the elimination of the conventional sucker rod couplings.
Numerical Study of the SAGD Process in the Burnt Lake Oil Sands Lease
Authors: Kisman K. E. , Yeung K. C. 
Published: December 2007

Abstract
A numerical study was conducted to predict recovery performance for the steam-assisted gravity-drainage (SAGD) process in the Burnt Lake oil sands lease. A geological and petrophysical description of the lease and a base case numerical model were prepared. Experience gained at the very successful Alberta Department of Energy Underground Test Facility (UTF) SAGD pilot was utilized in the numerical modelling.
The base case predicted favorable performance for a 1000 m long horizontal well pair, with a calendar day oil rate over 15 years of 70.1 m3/d, and an oil-steam ratio of 0.34. Optimisation of SAGD operations and factors such as spacing between well pairs will enhance the predicted performance.
Sensitivity studies showed that the SAGD process at the Burnt Lake site is expected to be robust, with a low to moderate sensitivity of recovery performance to reservoir properties within the range of uncertainty of these properties. The reservoir properties investigated include permeability, relative permeability, wettability changes, oil viscosity, thermal conductivity, flow barriers, and solution gas effects. Other factors investigated include operating pressure and placement of the production well. The only factor with a large effect on overall performance was placing the production well in a low permeability zone.
Coalinga Horizontal Well Applications: Present and Future
Authors: Huff Brian 
Published: December 2007

Abstract
The Etchegoin reservoir in the Coalinga Field contains over 40MMB of 10–11° API oil-in-place. The reservoir dips at about 14–20°. Following an infill program in 1991, remapping of the reservoir showed significant remaining oil in the downdip area.
Two downdip horizontal wells were planned and drilled in the Basal sand member. Together the wells develop a 25 acre area containing 1.1 MMBO. Production forecasts were generated using a simple analytical model. The model can predict initial production rates but is not adequate for gravity drainage situations. The paper discusses a number of special well design considerations.
Post-soak well performance was promising but showed the need for additional reservoir heat. Slim-hole injectors were added updip and near the horizontal wellbore. Today the two wells add 500 BDO to Coalinga production. This represents 10% of Etchegoin total production.
The Coalinga Team continues to look for additional horizontal well opportunities. Additional potential includes: 1) a new development area with multiple stacked sands of varying continuity, 2) a hot portion of the reservoir where steam entry into vertical wells causes impairment, 3) more downdip extension potential, and 4) a new thin reservoir with limited extent that might be a candidate for multi-lateral well technology.
Study and Practice on Recovery by Steamflood in Heavy Oil Reservoir with Edge and Bottom Water
Authors: Yuanqin Yao , Yingjie Zhou , Xianmin Li 
Published: December 2007

Abstract
This article provides an example of steamflood pilot which is a heavy oil reservoir with thick sandy formation and active edge and bottom water. It presents the cases of pilot emphatically such as performing steamflood conditions, opportunity, steamflood project, the characteristics of steamflood performance, some technical measures selected to improve steamflood effect and also furnishes a evaluation of developed results.
Cyclic Stimulation of Cold Lake Oil Sand With Supercritical Ethane
Authors: Lim G. B. , Kry R. P. , Harker B. C. , Jha Calgary K. N. 
Published: December 2007

Abstract
In a three dimensional scaled physical modeling experiment, Cold Lake oil sand was subjected to cyclic stimulation with supercritical ethane through a single horizontal injector/producer well located at the base of the reservoir. Hot ethane gas was injected into the bottom of the formation until the bottle hole pressure reached slightly above the ethane supercritical pressure of 4.9 MPa. Production of diluted bitumen followed the injection cycle through the same horizontal well until pressure in the reservoir was depleted slightly below 4 MPa. At that pressure liquid production rates were very low. During the experiment, temperature in the model varied considerably with the distance from the wellbore as well as with the number of stimulation cycles.
Supercritical ethane enhanced the cyclic solvent gas process by improving the early production rate. As well there was an increase of recovery of solvent in the blowdown at the end of the experiment. Both are important factors for the process economics.
Time animation of the temperature profile revealed that solvent gas preferentially invaded the region in close proximity to the production end of the horizontal well. The observation was consistent with the post test measurement of residual oil saturation in the model which showed that bitumen was preferentially depleted from that region. Evidently, full utilization of the horizontal well was not achieved in the experiment. Production enhancements would be expected if this technical deficiency could be overcome.