bluuebunny/crossref_metadata_2025_split huggingface dataset:
Formation Evaluation With Logs In The Deep Anadarko Basin
Authors: Peebler R.P. 
Published: December 2007

This paper was prepared for the Deep Drilling and Production Symposium of the Society of Petroleum Engineers of AIME, to be held in Amarillo, Tex., Sept. 11–12, 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 OF PETROLEUM TECHNOLOGY or the SOCIETY OF publication in the JOURNAL OF PETROLEUM TECHNOLOGY or the SOCIETY OF PETROLEUM ENGINEERS JOURNAL is usually granted upon requested to the Editor PETROLEUM ENGINEERS JOURNAL is usually granted upon requested to the Editor of the appropriate journal, provided agreement to give proper credit is made.
Discussion of this paper is invited. Three copies of any discussion should be sent to the Society of Petroleum Engineers Office. Such 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 complex lithology and the nature of the "measurement environment" make the "Deep -Anadarko Basin" one of the more difficult log evaluation problems facing the industry anywhere today. The paper describes methods for solving this problem.
The measurement environment is discussed in terms of perturbing effects on log readings. This includes a statement of what measurements are possible under various conditions of hole size, temperature, pressure, salinity, and gasified mud. The particular case of salt saturated drilling fluid, high temperatures and deep invasion is given special attention.
Application of the evaluation systems in use today to the Deep Anadarko Basin is discussed. This includes Quick-Look interpretation techniques employing the Dual Laterolog and/or the Compensated Neutron/Formation Density (Compensated) as well as the Advanced Computation System - CORIBAND.
The paper concludes that the evaluation systems available are capable of a highly consistent and reliable evaluation of this complex reservoir. However, as pointed out, cases exist where the measurements required for the evaluation system are sometimes deficient due to the harshness of the "measurement environment."

Introduction
Evaluation of the deep Anadarko Basin offers a difficult challenge: The Basin includes complex lithologies, high resistivities, variable shaliness, and both primary and secondary porosity. To find true porosity and determine lithology, both the porosity and determine lithology, both the Compensated Neutron and Formation Density logs are needed. If secondary porosity is to be identified, a Sonic log is also required. The use of these logs also offers avenues to gas identification, estimation of shaliness and advanced computer processing.
A variety of drilling fluids are in use, including fresh mud, salt muds, salt brines, and inverted emulsion muds.
Hamaca: Solution Gas Drive Recovery in a Heavy Oil Reservoir, Experimental Results
Authors: Treinen R. J. , Ring W. W. , Spence A. P. , de Mirabal M. , Huerta M. 
Published: December 2007

Abstract
Oil recovery greater than 10% OOIP in the Hamaca area of Venezuela's Orinoco heavy oil belt has been forecast based on field observations and experimental data.1,2 This high recovery can be modeled using drastically different mechanisms: a high critical gas saturation; a very low critical gas saturation combined with a large effective drainage area; or the formation of finely divided free gas that flows with its associated liquid. This paper details an experimental evaluation of solution gas drive recovery and the production mechanism present in the Hamaca region of the Orinoco heavy oil belt.
Critical gas saturation data were collected using a sand pack filled with live Hamaca crude oil at reservoir conditions. The sand pack was 2 inches in diameter, 12 inches in length, and had a pore volume of 200 cc. Pressure depletion of the pore fluids was achieved with a sequence of small fluid expansions. A flow rate was picked to mimic the fluid flux at 1000 ft from a vertical well. Pore fluids were allowed to reach phase equilibrium after every expansion. Pore and produced fluid compressibility, produced fluid gas oil ratio and CT scanner derived gas saturations were measured after every expansion.
As the pressure declined the produced fluid exhibited a decreasing GOR and a compressibility consistent with liquid while the sand pack fluids showed an increasing compressibility consistent with increasing gas saturation. Free gas production was observed by a simultaneous jump in the produced fluid GOR and compressibility and was also observed with CT scanner images. The CT scanner derived critical gas saturation was found to be 8.3 PV%. A material balance calculation indicated a critical gas saturation of 10.2 PV%.
CT scanner images showed free gas accumulating in gas rich regions which were generally surrounded by oil with little free gas. Gas saturation in gas rich regions could reach 70 PV%. As gas saturation increased, gas rich regions began to connect until a network of high gas saturation traversed the length of the sand pack. CT scanner images taken at the beginning of free gas flow were used to visualize this connected network of high gas saturation.
The experimental data show that the high solution gas drive recovery is the result of a high critical gas saturation. The data show that the high recovery is not associated to low critical gas saturation and a large drainage area. No finely divided foam or appreciable associated gas was observed in the produced fluid.
When a 9 PV% critical gas was combined with oil compressibility and the expected formation compressibility, field performance predictions yielded a 12.5% OOIP oil recovery estimate.
Optimal Design and Planning for Laboratory Corefloods
Authors: dos Santos Renato L.A. , Bedrikovetsky P. , Holleben Carlos R. 
Published: December 2007

Abstract
In the design of routine coreflood tests, it arises a number of limitations for physical similarity (capillary number, end effect) and for laboratory equipment restrictions (accuracy of measurements, pump capacities, etc.), which restrict the test plan. In the current paper these restrictions are presented in terms of dimensionless parameters. These limitations result in a system of inequalities for core length and displacement velocity. For the cases of waterflood and EOR, the sets of significant parameters have been determined. The code written in a simple spreadsheet allows to determine minimum core length which provides fulfillment of above mentioned conditions and to calculate the optimal displacement velocity.

Introduction
Relative phase permeabilities are the basic functions which determine the efficiency of the waterflooding. Hence, the accurate laboratory determination of these functions from the routine coreflood procedure is an important problem of the waterflood design and planning.
Well developed and widely spread routine unsteady state method for determination the relative permeability assumes that capillary forces are neglected, i.e. so called conditions for large scale approximation are fulfilled. This could be achieved for long cores. The major limitation for this study is the core length, which usually does not exceed 13–20 cm. The problem of designing the routine coreflood test is to find out whether the conditions of classical methods are fulfilled for a given core, and to find the displacement velocity which provides the minimum error.
Number of works propose different methods for determination of the relative permeability honouring capillary pressure. The approximate methods are reliable for limited intervals of rock and fluid parameters. Optimisation methods lead to ill-posed inverse problems. Therefore, the JBN method is still used routinely.
In the current paper we concentrate on conditions of validity for routine JBN method and on parameters for laboratory test which provide this validity.
Criteria for physical similarity for waterflooding (limited capillary number, minimum capillary-viscous ratio and delay number) were used in the work of Bedrikovetsky et alii for planning the coreflood test based on Barenblatt's non-equilibrium theory. Alternate criteria for large scale approximation are minimum sizes of stabilized capillary zone and of end effect zone which also provide minimum core length and optimal velocity.
Nevertheless, during routine tests arise operational limitations like accuracy of measurements, capacity of pumps, etc. which are to be considered with the test design.
In the current work we concentrate on design of the coreflood honouring both physical similarity criteria and operational limitations. Simple software in a spreadsheet is developed to determine minimum core length and optimal displacement velocity for waterflood and EOR.
Analysis of Flow in Spatially Correlated Systems by Applying the Percolation Theory
Authors: Salomao M.C. 
Published: December 2007

Abstract
The percolation theory provides universal laws which are helpful to describe geometrical and physical characteristics of a system. The present work verifies the influence of spatial correlation on percolation parameters and, as a consequence, on fluids flow properties. Monte Carlo simulation of stochastic processes was applied in association with the percolation theory of finitesized lattices, and with the invasion percolation model. In the first part, the sensibility of percolation parameters (as the percolation threshold and the connectivity function) to autocorrelation function in Gaussian process, and to attraction parameter in Markovian processes is observed. In the second part, the invasion percolation model is applied to inspect the behavior of fluids flow in pore-grain systems. The results show that spatial correlation plays an important role in the description of porous stems, strongly affecting the flow properties, the values of fluids recovery and residual saturations.

Introduction
The percolation theory, as termed by Broadbent and Hammersley in their classical work of 1957, was conceived to describe the morphology and nature of fluids transport in disordered media. It has undergone great progress, in several fields of science (physics, biology, chemistry), and has the distinguished quality to provide universal laws that describe the geometry and general properties of the tem. An important aspect concerning the percolation processes is the fact that its dynamics is ruled by the medium and not by the fluid, having outstanding importance the geometric and statistic characteristics of this medium.
Assuming initially a square grid in which the cells are conductor of energy or insulate, let us suppose that a fraction p of them is conductor and randomly located at the grid, that is, each cell has a probability p of being conductor, independent of any other cell. Supposing that the energy propagation occurs only through conductor cells having a common face, the energy imposed to the top line may be transmitted to the bottom line or not; the passage of energy between opposite bounds is called percolation. ft can be noted that the greater the proportion of conductor cells, the greater the probability of occurring percolation; in addition, percolation only occurs above a certain proportion, called critical concentration or percolation threshold - pc. This model, in which the lattice is formed of connected cells, is denominated site percolation. A similar ease, in which all the cells are active, but the connections between them, called passages or bonds, may be active or not, is denominated bond percolation. These models are used to represent binary systems as permeable rock and shale, pore-grain systems, wetting fluid and non-wetting fluid, positive and negative spins, etc.
Combined Artificial Lift System - An Innovative Approach
Authors: Saputelli L. 
Published: December 2007

Abstract
Artificial lift methods such as gas lift and electric submersible pump offer great advantages in improving vertical flow performance and oil well productivity. Each method has its own limitations and disadvantages as well.
A combined artificial lift system is proposed to improve oil well productivity and to overcome as many of the disadvantages as possible. The objective is to minimize total energy requirements to maximize production.
Major benefits of combined artificial lift are to reduce initial capital and operation costs, by optimizing compression gas and electricity requirements and to reduce abandonment pressure leading to higher recovery. Main applications areas include new and developing fields mature fields, fields with low gas supply, low PI and deep wells.

Introduction
Millions of barrels of oil remain virtually inaccessible in reservoirs because of the limitation on the abandonment pressures. Hopefully the new advent of technology in artificial lift mechanism will enable the production engineers to recover a part of the oil left behind by lowering the abandonment pressures.
Reservoir pressure declines with time due to net extraction of fluids. With the declining pressure, the operating artificial lift mechanism eventually fails to lift the wellbore fluids to the surface and consequently, the well dies. Therefore, it becomes necessary to switch to a more efficient lifting technology that can operate at lower pressures and thereby extend the well life. When all economic lifting methods have been tested in accordance with the availability of surface facilities, the reservoir is said to have reached the optimum abandonment pressure.
Inflow performance (Figure 1) is proportional to drawdown pressure (P), i.e., the difference between reservoir static pressure and the flowing bottom-hole pressure (Pwf).
Updated Field Case Studies on Application and Performance of Bottom Drive Progressing Cavity Pumps
Authors: Haworth Cameron G. 
Published: December 2007

Abstract
Until recently, the Progressing Cavity Submergible Pumping System (PCSPS) has only been used where a conventional top drive system was prone to frequent failure. However, recent studies on PCSPS applications have provided ample evidence that the PCSPS is an excellent alternative for many slant, deviated and horizontal progressing cavity pumping applications. The PCSPS with its proven longevity may also become a viable and economic method for vertical well progressive cavity pumping applications.
Evaluation of the retrieved downhole drive system from these applications has shown the units, in most cases, were in excellent condition and with minor tune-up and testing the equipment was again ready for service.

Introduction
The progressing cavity pump made its first appearance in the Petroleum Industry in the 1970's by producing heavy crude oil with high concentrations of sand and solids. Since that time the application of the progressing cavity pump has expanded to include medium to light grade oil production as well as water source wells. In many cases the progressing cavity pump is the only viable method of lift in certain types of oil bearing reservoirs. This broader spectrum of applications and the relatively low capital cost and high system efficiency has significantly increased the use of progressing cavity pumps around the world. The increased use in a wide variety of applications has brought to light some of the deficiencies in the top drive progressing cavity pumping system. This paper will cover several field case studies illustrating the advantages of the bottom drive progressing cavity pumping system over the conventional top drive system.
Bottom Drive Progressing Cavity Pumping System - The PCSPS Progressing Cavity Submergible Pumping System (PCSPS) is a system consisting of a submergible motor rotating the progressing cavity pump from below, thereby eliminating the long failure prone sucker rod drive shaft.
There are several operational considerations in the development of the PCSPS.
The Telford Field Development
Authors: Jewell Stephen , Ward Christopher 
Published: December 2007

Abstract
The Telford field is an oil and gas accumulation located in the UK sector of the North Sea. As a subsea tieback to existing production infrastructure this development might at first appear to be typical of many similar projects completed in recent years. However, the Telford story is interesting for two reasons. Firstly, the individual reservoirs making up the development are very different in nature and would be uneconomic on a stand alone basis. Secondly, the rapid development of the area to ensure maximum project value was a critical success factor. Achieving this hinged on the speedy resolution of a cross boundary equity issue which subsequently led to the formation of a joint operator sub-surface team for the reservoir development.
This paper focuses on the sub-surface aspects of the development and how the application of state-of-the-art technology coupled with a phased approach has led to the development of what was previously considered to be a marginal field. The rapid commercial agreement reached to enable the development to proceed and the success of the joint sub-surface team are considered. The paper aims to demonstrate that even small, complex accumulations can be developed successfully by an experienced operator determined to overcome traditional barriers to success.

Introduction
The Telford Field is located in Blocks 15/21a and 15/22 of the United Kingdom Continental Shelf. The area is located approximately 170 km northeast of Aberdeen, 9 km south of the Scott Platform. The Telford field is an elongate structure measuring 11 km by 1 km. It comprises four separate accumulations trapped within structural compartments of late Jurassic Piper Formation sandstones. The reservoir is sealed and sourced by the overlying Kimmeridge Clay formation which is also Late Jurassic in age. The various accumulations have been named Central, West and East Telford and Marmion. Total STOIIP prior to development was estimated to be between 107 and 126 mmstb with a corresponding GIIP of 181 to 211 bcf. The location of the field and each accumulation is described in Fig. 1.
Full exploitation of the Telford area will ultimately be achieved by a two phase development. This will consist of the tie-back of sub-sea completed wells via manifolds and flowlines to the Scott Platform. The phasing of the development is to allow for processing restrictions at Scott and to permit further appraisal of the field. Phase 1 is now complete and has seen the development of the core area consisting of Central Telford and Marmion. Phase 2 will involve the appraisal and development of the West and East Telford areas and of the West Marmion prospect.
This paper describes the first phase of the development and the initial appraisal of West Telford. The second phase of the Telford development is expected to begin in 1998.
Stimulation Program in High Permeability Oil Sands - Case Study
Authors: Davidson B. M. , Franco V. H. , Gonzalez S. , Robinson B. M. 
Published: December 2007

Abstract
Argosy International operates several oil fields in southern Colombia, South America that were experiencing a significant decline in productivity. A study of numerous wells in these fields revealed the decrease in productivity was due to increasing skin damage near the wellbore. Lab tests and field observations indicated that fines migration and asphaltine deposition were the most likely causes. Several types of treatments were performed during a pilot program to overcome the near wellbore damage, including acid treatments, xylene treatments, clay stabilizer treatments, high pressure gas fracturing and hydraulic fracturing. The hydraulic fracture treatments provided the best results and justified the economics of implementing a major stimulation program. A total of 17 fracture treatments have been performed on 10 different wells. As a result, the productivity of the wells has increased by 2–3 fold, the total field production has increased substantially. As of February 1997 an additional 2,700,000 bbls of oil has been produced as a result of the fracturing program. The implementation of quality control and real-time analysis using a 3-Dimensional fracture model has allowed for on-site revisions of the fracture treatments. The amounts of pad and proppant volumes were optimized to achieve a proppant pack off in the fracture at the end of the flush.
Use of External Parallelization to Improve History Matching
Authors: Schiozer D.J. , Sousa S.H.G. 
Published: December 2007

Abstract
Although automatic history matching is a difficult task due to production and reservoir characterization uncertainties, it is possible to develop methodologies and computer programs to improve the matching process.
An important tool in the development of this type of methodology is the external parallelization of reservoir simulators where simulations can be divided into a network of workstations, reducing significantly the total time of the process, especially for some network types.
This work shows some applications of the use of external parallelization applied to the history matching process. Due to the high the number of simulations which are necessary, a routine was created to distribute the runs over a network of workstation. The software PVM (Parallel Virtual Machine) was used and an algorithm was developed to make the best use the target network.
There is a great number of applications of this technique in reservoir simulation. Every application which requires several simulations can be improved with external parallelization. A routine to manage all simulations is very important to make the best use of a network.

Introduction
The modeling of hydrocarbon reservoirs can be so complex that many times the only possible and reliable technique to be used is making adjustments in the reservoir model until numerical simulators results match observed production data. Such a process, known as history matching, is usually very slow due to the high number of variables and degree of uncertainty and heterogeneity of reservoir parameters.
The complexity of the process leads most people to believe that automatic history matching is neither viable nor possible. For this reason, "trial and error" procedures based on personal experience is a common practice.
However, recent hardware and software developments can be used to accelerate a history matching process, making it faster and more reliable than "trial and error" procedures. Although it is not yet possible to have the whole process automatic, the automation of several steps is both possible and necessary.
This work deals with one important tool which can be used to accelerate history matching which is external parallelization, i.e., the use of a software to efficiently distribute simulation runs that can be performed in parallel in an existing network of workstations. The software developed in this work (MPS - Multiple Parallel Simulations) is based on PVM (Parallel Virtual Machine) libraries.
The applications cited here are specifically applied to history matching but they can be used to any process that requires several simulation runs. The ultimate application of MPS is to manage all simulations on a network.