bluuebunny/crossref_metadata_2025_split huggingface dataset:
A Brief Description of Extended Well Testing (EWT) System
Authors: Wu Si 
Published: December 2007

ABSTRACT
This paper discusses mainly the component, characteristics and main uses of extended well testing system, main factors considered in design, and the system application. Component of the system: the system is mainly composed of jack—up platform, floating hose, 2 — point submarine buoy mooring system, and storage tanker.Characteristics of the system: the system can use fully the existing equipment with less investment, gaining benefit early, flexible operation, safety and reliableness, repeated utilization, easy to relocate and low cost.Usage of the system: the system is used in reservoir testing before development reservoir data can be got, reliable asis can be provided for the policy making of oil field development, and the developing risk of oil field can be reduced through the testing. Furthermore, the system can be also used in the development of marginal fields.Main factors considered in the designs the system adopts firstly the new technology of 2—point submarine buoy mooring system and simple process flow sheet with only degassing and no dehydration. Reliable measures are taken to ensure safety production from the angle of design and usage.Usage condition: it is proven by practice that connection and disconnection of the system are very convenient with flexible operation and reliableness. The shuttle tanker can be moored side by side conveniently using 2 — poit submarine buoy mooring system.
The Oil-Water Relative Permeability Behaviour of A Low Permeable Reservoir
Authors: Kevin Li , Yirong Jiang , Zhijian Dai , Ying Hong 
Published: December 2007

ABSTRACT
Much attention is now paid to the development of low permeable reservoirs. However, there is almost a dearth of literature on the study of relative permeabilities in rock samples with low permeability. Group J2S of QL Reservoir is characteristics of low porosity, low permeability and low crude oil viscosity.
Oil-water relative permeabilities of QL Reservoir have been measured at two different oil/water viscosity ratios by using unsteady-state method. The experimental results showed that the oil-water relative permeabilities change with the changing of oil/water viscosity ratio. It is explained that the oil-water relative permeabilities measured at oil/water viscosity ratio close to the oil/water viscosity ratio under reservoir condition coincide with the practical situation of QL Reservoir by comparing the injection-production ratio calculated from laboratory water flooding data with the practical one.
The irreducible water saturations in QL Reservoir rocks range from 27.7% to 35.8% and its average value is 31.5%. The water flooding residual oil saturations range from 11.6% to 21.7% and its average value is 14.8%. Most of the water relative permeabilities at residual oil saturations range from 0.23 to 0.50 and its average value is about 0.388. Oil-Reference and illustration at end of paper water 2-phase flowing limit ranges from 47.8% to 59.0% and its average value is about 53.7%. Moreover, the end water relative permeabilities are correlated with the air permeabilities of rock samples. That is, the bigger the air permeabilities of the rock samples, the higher the end water relative permeabilities.
A Field Study of Horizontal Well Design in Reducing Water Coning
Authors: Wu G. , Reynolds K. , Markitell B. 
Published: December 2007

ABSTRACT
Water and gas coning is a serious problem in many oil field applications. In reservoirs with bottom water, vertical wells are normally completed in the top section of the pay zone to minimize water coning. Similarly, in a reservoir with a gas cap, a vertical well is perforated as low as possible to delay gas coning. Oil production from thin oil layers sandwiched between a gas cap and bottom water, such as one finds in the Amber Field in the Gulf of Mexico presents difficult coning problems in vertical wells.
This paper describes Texaco's efforts to evaluate, justify and drill a horizontal well in Amber Field. The target reservoir contains a very thin pancake oil zone sandwiched between a large gas cap and a strong bottom water aquifer. The production wells were expected to exhibit critical oil rates of approximately 10 STB/day (calculated). Due to the gas and water coning, the vertical wells in the field produce at low oil rates and recovery was in the range of 3% to 4%. This paper details efforts to numerically model the optimum case for vertical and horizontal wells to allow for economic comparisons. The effect of the length of the horizontal wells, their location relative to the current fluid contacts, and the change in performance with production rate are all investigated.
The simulation process involves four individual steps: (1) history matching the adjacent well with coning problems, (2) assessing the current fluid distribution by a coarse-grid model with single-phase producers, (3) calculating the initial rate of a horizontal well, and (4) horizontal-well performance prediction. It is demonstrated that the optimal well position depends on the development term. A horizontal well penetrating the oil column produces more oil and water during the early stage of horizontal well production. In the long run, it appears to be beneficial to place the horizontal well in the gas cap, which gives the highest oil recovery and significantly reduces water coning.
Formation Damage due to Losses of Ca-Based Brine and How it was Revealed Through Post Evaluation of Scale Dissolver and Scale Inhibitor Squeeze Treatments
Authors: Lejon K. , Thingvoll J. Tuxen , Vollen E. A. , Hammonds P. 
Published: December 2007

ABSTRACT
Calcium based brine has regularly been used during workover operations on naturally completed wells without any sign of formation damage, in gravel packed wells which have seen severe losses of Ca based brine production decline was observed.
For some of the gravel packed wells the production decline occurred when bringing the well on production after completion, whilst in others, the loss in productivity occurred after sea water breakthrough.'
In order to increase productivity and confirm the relationship between productivity decline and formation of CaSO4 scale due to losses of completion brine, scale dissolver treatments were carried out.
The use of dissolver chemicals resulted in mobilization and removal of several hundred kilograms of solids from the near wellbore area.
A post-evaluation strategy to provide information about the nature, origin and location of scale was successfully implemented. More importantly, the dissolver treatments resulted in increased oil production.
The findings and lessons learned have had several important implications for gravel pack completions and well treatments in Statoil.
Fractional Pore Volume Acidizing Flow Experiments
Authors: Gdanski Rick 
Published: December 2007

Abstract
A large amount of published literature exists detailing the effects of HF on sandstone cores.1 The bulk of this work concerns flowing large numbers of acid pore volumes through relatively small cores having pore volumes of about 5 to 15 mL. Some HF acidizing studies have analyzed the effluent from these tests to determine ionic composition in an effort to study the chemistry of HF acidizing. Chemical and engineering simulators use the results of such work in an attempt to predict the performance of HF in sandstone formations.2-6 Returns analyses7-9 from many wells treated with HF do not support the results of these multiple-pore volume flow tests and associated simulators. Some researchers now use long-core permeameters to improve the prediction of the laboratory tests and to answer key questions concerning well response to HF acidizing treatments.10-13
It has been recognized that inadequate laboratory experimental models have caused the discrepancies between the experiments and the well returns. To solve this problem, a laboratory acidization apparatus has been designed, constructed, and tested. The apparatus has a pore volume of about 300 mL, which allows fractional pore volume tests to be conducted and effluent to be analyzed on the basis of fractional pore volume. For such a test to be analyzed, the effects from mixing and ion exchange must be considered. A computer code written explicitly for the apparatus evaluates the effluent ionic data.
The apparatus is essentially a 3-ft Hassler sleeve with multiple pressure taps. The sleeve can be packed either with a blend of sand and clay or loaded with a solid core. Two computers and two microprocessors networked together control temperature, valve switching, pressure measurements, flow measurement, pump control, and data collection. A typical two-to four-pore volume experiment requires about 4 to 24 hours to complete, depending on pump rate.
The new apparatus successfully has modeled (1) mixing between two separate fluid stages, (2) ion exchange on bentonite with various brines and acids, and (3) leaching of aluminum from clays by HCl. Results indicate that the new apparatus and analysis tools are particularly suited for the study of HF acidizing chemistry.
Evaluating the Performance of Open-Hole, Perforated and Fractured Water Injection Wells
Authors: Pang Shutong , Sharma Mukul M. 
Published: December 2007

Abstract
The performance, i.e. the half-life of water injectors, is very important to the economics of water injection projects. A simulator is presented to predict the decline in injectivity of water injection wells. Equations are presented that allow us to model open-hole and perforated completions as well as fractured wells. The mechanism of injectivity decline can be determined by comparing core flow test data with one of four type curves. The transition time is used to determine when external filtration becomes dominant so that the appropriate models can be used for early and late time.
The simulator can be used whether or not core flow data is available. Empirical equations are provided to estimate the filtration parameters if core flow test data is not available. The simulator is easy to use, has interactive input and output and is available for PCs and Unix workstations. Examples are provided to show how the simulator can be used to predict the performance of injectors in a variety of cases. The simulator predictions are compared with experimental data. The simulation results are then used to suggest the optimum water quality that will minimize the total cost of water treatment and periodic well stimulation.
Alba Field Cased Hole Horizontal Gravel Pack - A Team Approach to Design
Authors: Alexander Karen , Winton Suzanne , Price-Smith Colin 
Published: December 2007

ABSTRACT
A 700’ cased hole horizontal well was gravel packed and completed in the Alba Field, Central North Sea. The completion incorporated a number of new technologies adopted for a horizontal cased hole completion including both equipment and fluids. The zone was completed in 2 stages using a horizontal stack pack approach. Perforation packing was optimized by performing a staged acid prepack with the guns in the hole utilizing a low density synthetic gravel substitute in a shear thinning carrier fluid. This was a world first achievement at a cased hole gravel pack using the stack pack approach in a horizontal well. A solids free fluid loss control material was evaluated and chosen for the high permeability Alba sands (3 Darcy). Extensive lab testing was performed to ensure minimal damage from various fluids. A 30' physical model was used to optimize annular pack efficiency. A gravel placement computer simulation was used to design pump rate, sand concentration and gel loading in order to optimize annular and perforation pack efficiency.
Quantifying Porosity and Estimating Permeability from Well Logs in Fractured Basement Reservoirs
Authors: Sibbit Alan M. 
Published: December 2007

Abstract
Low porosity fractured reservoirs have been successfully described using a combination of high resolution geometrical information from borehole images together with deeper penetrating log evaluation methods.
Borehole images from acoustic or electrical scanning tools provide statistics of fracture distribution, first order estimates of fracture opening and porosity, and a basis for geological inference. Their drawback is that, in this environment, the events on the images bear a strong overprint of the drilling process. Deeper penetrating but lower resolution techniques such as Stoneley wave reflectance and deep resistivity log inversion are used to distinguish the deep and permeable fractures that may contribute to flow.
By making some assumptions about the nature of the porosity in basement reservoirs we develop a new method to estimate the porosity and the fraction of this porosity due to fractures. This method makes use of the Kuster-Toksoz acoustic scattering model and requires low frequency measurements of compressional and shear velocities.
Efficient Development Drilling From a Twelve Well Platform
Authors: Eaton Ben A. , Mosley Mark K. , Beakley Bill 
Published: December 2007

Abstract
This paper presents the results of a case study that was undertaken to determine the reasons for the unusually rapid development of a twelve well platform, the third such platform in the immediate area.
Factors that contributed to the successful drilling and completion of these wells are discussed. The overall contribution of the master plan for development is discussed as well as the role of the individual well plans. Specific drilling practices are covered such as the details practices are covered such as the details of the bottom-hole assemblies used for directional control. Since the subject wells were directional slant type holes with high drift angles, primary cementing was of great concern. Cementing techniques that were used successfully are presented. It is shown that a 25 per cent reduction in drilling and cementing time was achieved in this case compared to past practices.
Some of the completion practices were unique for this area and these practices resulted in a further time savings. The overall completion and sand control procedures are discussed in the paper. procedures are discussed in the paper. It is concluded that proper planning. utilization of proper equipment and materials, and excellent on-site rig supervision were the most effective factors in reducing costs for this operation.

Introduction
This case study was initiated due to the unusually fast development drilling from this particular platform. Especially interesting particular platform. Especially interesting was the fact that this was the third such platform in the immediate area. The previous platform in the immediate area. The previous wells had been drilled and completed with the same rig on the second platform and by a very similar rig on the first platform.
In each case a twelve well platform was installed in approximately 170' of water. The platforms were designed to accommodate a minimum size, self-contained rig. Drive pipe guides were arranged in two parallel pipe guides were arranged in two parallel rows of six wells each. Normally, drive pipe was driven in the center six slots at the time the platform was installed. From that point on the work was done with the small, point on the work was done with the small, self-contained rig.
Real Time Expert System (R.T.E.S.) for Rod Pumping Optimization
Authors: Vázquez O. Manuel 
Published: December 2007

Abstract
Through Real Time Expert Systems (R.T.E.S.) technology, it is possible to remotely monitor and control, IN REAL TIME, Rod Pumping automated fields seeking to guarantee maximum production, minimum operating cost, and extending the useful life of equipment.
In Rod Pumping Systems there are analytical tools which allow diagnosing the behavior of the wells[1],[2], such as Dynagraph Charts, Pressure Loggings and Current Consumption. These Loggings are interpreted (using Design and Completion Information) in order to analyze, diagnose the state of the well and finally issue a recommendation, bringing as a result a field action. Generally, these actions are based on S.P.M control of the wells and this can be done automatically, closing the Control Loop.
The main advantage of R.T.E.S consists in the REAL TIME event detection and the immediate reaction to that event. Moreover, the integration of R.T.E.S with Mathematical Models and Simulation Models allows to predict events before they happen and to take field actions.
"OFFSHORE MERCURY" and Her Maiden Voyage
Authors: Blight Graham J. 
Published: December 2007

Abstract
The OFFSHORE MERCURY is a self-propelled self-elevating drillship which can undertake unaccompanied major ocean voyages and field moves. She can be used for exploratory or development work in the offshore oil and gas industry.
Because of her self-propulsion capability the vessel is classified and registered just like a ship. As a result of this, some technical and legislative problems arose during construction and in respect of her operation. Some of these matters are considered with reference to the corresponding solutions which were adopted so that the appropriate rules of the regulatory bodies were satisfied.
All major construction and necessary outfit work was completed and the vessel sailed from the River Clyde in Scotland on December 16th, 1969. Thus the Mercury commenced her maiden voyage en route to Bahia Blanca in the Argentine. The significance of this voyage as a proving experience for the design and engineering of the concept is described in the narrative.
PRELIMINARY REMARKS PRELIMINARY REMARKS Nearly three years ago it was decided that the drilling capabilities of a successful and proven design of self-elevating platform should be combined with the self-propulsion characteristics of a normal ocean-going ship.
The beauty of this idea lay in the long term economic advantages to be gained, insofar that the burdensome expense of tugs would be eliminated at times of maneuvering on, or of changing location. In addition it was apparent that significant savings on the cost of voyage insurance could be made since the vessel would sail under her own power. This is not so expensive as the greater risk assumed by a towed vessel. Also, with an appropriate speed the vessel would get to location faster than if towed and thus in the long term spend a greater proportion of her time in the drilling proportion of her time in the drilling or earning capacity.
The philosophy of the initial design process and development for this new process and development for this new class of drillrig was presented to the Offshore Technology Conference 1969 (ref. 1).
Predicting Production Using a Neural Network (Artificial Intelligence Beats Human Intelligence)
Authors: Boomer Robert J. 
Published: December 2007

Abstract
Petroleum professionals, that is engineers and geoscientist, routinely make recommendations to drill wells. This process requires the generation of a production profile, oil producing rate versus time, which is a key component in the final economic decision of whether or not to drill the well. The success of the drilling program, and possibly the professional's career, rests, to a high degree, upon the accuracy of this predicted production profile. The more accurate this prediction the more certain the economic value of the recommended drilling location. This paper looks at this predictive process as used in the Vacuum Field of New Mexico. It explores the predictive methods used in the past and reports on their accuracy. A new method, using artificial intelligence, is presented which improves upon the accuracy of this process.
Parallel Processing Applied to Local Grid Refinement
Authors: Bowen Garfield R. , Leiknes Jorgen 
Published: December 2007

Abstract
Hybrid gridding techniques provide simulation engineers with an efficient technique for refining a simulation grid in regions of the reservoir where fine detail is required. Local grids are usually required near wells to resolve coning effects. This paper describes the implementation of a hybrid gridding system where the individual local grids are processed on separate processors.
The implementation is suitable for a range of distributed memory parallel computers including a cluster of workstations linked by an Ethernet type local area network.
The basic algorithm solves the global grid with large time steps. This establishes boundary conditions for the local grids which are solved independently with small time steps. The global grid is computed on a master processor with a number of slave processors for the local grids. The algorithm allows the dynamic load balancing of the parallel work and provides a fault tolerant system for the local grids.
The system is applied to a full field simulation study, employing a network of workstations. The performance is assessed on both a dedicated cluster of machines and in a typical oil company working environment.
An Algorithm for the Visualization of Stochastically Generated Colour Images of Reservoir Attributes, Structural Information and Reservoir Boundaries
Authors: Oscar G. , González H. 
Published: December 2007

Abstract
Visualization of reservoir models, integration of a variety of relevant information and generation of final maps on both computer screen and paper, are important parts of reservoir modelling work. The automation of the map generation process enhances the visualization of models integrating multiple geological features, improves quality and reduces time requirements.
This paper presents an image processing algorithm, developed on workstations, which enhances the integration of information used in visualizing and representing reservoir models and related geological-engineering characteristics. The algorithm can integrate images of: Stochastically generated colour maps of reservoir attributes.Scanned structural reservoir maps including faults as well as borehole locations and names.Scanned maps of reservoir boundaries.
This information is digitally integrated into a single colour map that can be manipulated on the screen or printed on paper. Part of the work is developed to extend the visualization of two dimensional maps such as structural maps into three dimensions without relying on digitizer tables. The practical aspects and visualization capabilities of the algorithm are demonstrated with examples.
An EUB Review of In Situ Oil Sands Bitumen Production
Authors: Sadler K. W. 
Published: December 2007

Abstract
The Energy and Utilities Board (EUB) has, as part of its mandate, responsibility for ensuring the orderly, efficient and economical development, in the public interest, of the oil sands resources of Alberta. With increased focus on oil sands production to replace conventional oil, the EUB sees bitumen production as playing an increasing role as a secure source of energy supply.
The EUB forecast of bitumen production from in situ oil sands projects shows an increase from 21 500 m3/d in 1994 to 33 000 m3/d by the year 2000. This forecast and the historical drilling and production patterns associated with commercial, experimental and primary recovery projects will be reviewed. In addition, comments on horizontal drilling activity and the production attributable to horizontal wells are provided.
Oil sands project development occurs using many different methods and in many different reservoirs. Data on production attributable to the various oil sands formations and the established reserves volumes to year-end 1994 are discussed.
The EUB also maintains a very extensive database on Alberta's oil sands production. A description of the data storage and dissemination capabilities is provided.