bluuebunny/crossref_metadata_2025_split huggingface dataset:
Development of a Multiple Application Reservoir Simulator for use on a Vector Computer
Authors: Kendall R. P. , Morrell G. O. , Peaceman D. W. , Silliman W. J. , Watts J. W. 
Published: December 2007

ABSTRACT
This paper describes a new reservoir simulator possessing four distinctive features: (1) It uses a recently developed formulation that is efficient in both black-oil and compositional modeling. (2) It possesses a design that permits it to solve efficiently very large problems on a vector computer while being reasonably efficient on smaller problems and on scalar machines. (3) It uses a novel approach to data management that permits writing most of the program as if it rar in core despite the fact that, in general, data is continually being temporarily stored on and retrieved from disk. (4) Its well management package uses a flexible data structure and logic sequence that permits modeling of complex well and surface facility networks.
The paper presents an overview of the simulator, discussing each of the features mentioned above. It also briefly discusses our experience to date in using the new program and the conclusions we have reached based on this experience.
Application of Rosenbrock Search Technique to Reduce the Drilling Cost of a Well in Bai-Hassan Oil Field
Authors: Aswad Zeiad A. R. , Al-Hadad Saad M. S. 
Published: December 2007

ABSTRACT
The powerfull Rosenbrock search technique, which optimize both the directions of search using Gram-Schmidt procedure and the step size using Fibonacci line search method, has been used to optimize the drilling program of an oil well drilled in BAI-HASSAN oil field, KIRKUK IRAQ, using the two dimensional drilling model of Galle and Woods. This model shows the effect of the two major controlable variables, weight on bit and rotary speed, on the drilling rate while considering the other controllable variables such as; mud properties, hydrostatic pressure, hydraulic design, and bit selection are well chossen. Also the effect of tooth dullness on the drilling rate is considered in this drilling model.
Increasing the weight on bit with a little increase or decrease in rotary speed gave a significant decrease in the drilling cost for most bit run. A 48 % reduction in the total drilling cost and a 97 hours saving in the total drilling time can be obtained by optimizing the drilling program of any well that will be drilled in the same formations using the same types and sizes of bits, the same drilling fluid properties, and the same hydraulics program.
The Rosenbrock search method using Fibonacci line search reached to almost the same optimum drilling cost for most bit runs from different starting points that are far away from the optimum, which shows the ability of this technique to solve and optimize the drilling function given by Galle and Woods.
Primary Cementing Across Massive Lost Circulation Zones
Authors: Turki W. H. , Mackay A. S. 
Published: December 2007

ABSTRACT
As a result of severe lost circulation problems in some wells in the Ghawar and Abqaiq Fields, Aramco has been unable to cover the Umm Er-Radhuma (Paleocene) and Wasia (Cretaceous) aquifers with cement. This has necessitated setting an extended liner opposite the Wasia aquifer, to ensure that there are two casing strings and a cement sheath across the aquifer, resulting in increased casing cost and reduced well productivity.
This paper will describe the results of field trial tests performed, along with conclusions and recommendations aimed at solving this problem.
Field methods employed include light weight extended cements, ultra-light cement slurries weighing as low as 55 lbm/ft3 (pcf), using ceramic hollow spheres, glass bubbles and foam, plus hydrostatic cementing, and mechanical devices.
Finally, methods of job evaluation will be discussed. These include temperature surveys, bond logs, radioactive tracers, and a new cement volume log.
Detection and Remedy of Behind-Casing Communication During Well Completion
Authors: Abdel-Mota'al A. A. 
Published: December 2007

ABSTRACT
Detection and remedy of behind-casing communication is a problem during selective completion of wells on two zones of a multilayered reservoir, where the length of separation between the two zones is critical. This paper presents a new technique - Communication Test-Completion Procedure - which is applied in Abu Dhabi oil fields to overcome this problem.
Improved Oil Saturation Data Using Sponge Core Barrel
Authors: Park Arthur , Devier C. A. 
Published: December 2007

ABSTRACT
Sponge core barrel is proving to be a convenient, economic and acceptable method to obtain improved oil saturation data. Research and development has continued to improve this new tool that is being developed for enhanced recovery operations. The sponge barrel is not only being developed for improved oil saturation but to determine water saturation and CO2 in cores under controlled conditions.
Stimulation Treatment Design and Evaluation of Old Producing Wells
Authors: Sinha B. K. , Elbel J. L. 
Published: December 2007

ABSTRACT
The productivity of many old producing wells can be increased by the use of a properly designed stimulation treatment. The majority of these wells, both pumping and nonpumping, are fractured. Partial healing of the hydraulic fracture may occur as pressure declines in the reservoir. In addition, other common forms of formation damage occur with time. An accurate evaluation of the existing conditions in the well is required for proper design of the stimulation treatment.
In this paper, an attempt has been made to utilize production data and pressure transient test data simultaneously to evaluate the existing condition of the well. The use of published type-curve techniques for unfractured, fractured and decline curve analyses has been emphasized to eliminate ambiguities and to arrive at a reliable conclusion. Both conventional pressure data and liquid-level measurement data have been used in this study. A two-dimensional simulator has also been used to aid stimulation treatment design and performance evaluation.
North Burbank Unit Commercial Scale Polymerflood Project—Osage County, Oklahoma
Authors: Moffitt P. D. , Mitchell J. F. 
Published: December 2007

ABSTRACT
The North Burbank Unit commercial scale polymerflood project began in September, 1980, with the injection of fresh water preflush within a 1440 acre polymerflood project area. Since that time polymer solution at 500 ppm concentration, interrupted by aluminum citrate, and polymer solutions of 2 50 and 50 ppm concentration have been injected. The total polymer to be injected is 4,001,000 pounds of a liquid emulsion polyacrylamide.
This paper deals with operational problems encountered during the project and the response of the project wells to polymer injection. The discussion of operational problems includes shear degradation of the polymer solution, disposal of produced brine, biocide effectiveness, and near wellbore treatments to adjust injection rates into individual injection wells. The response of the project producing wells includes fresh water breakthrough, polymer production, and oil production response to polymerflooding. The discussion of the response of the project injection wells includes injection rate and wellhead pressure histories, and analysis of pressure falloff tests before and during polymer injection.
The project area has responded positively to polymer injection with the production rate from the project area currently averaging 951 barrels of oil per day compared with a pre-project rate of 510 BOPD. The producing water-oil ratio has correspondingly declined frcm a pre-project water-oil ratio of over 100 to a current ratio of less than 50. The interior pattern wells have shown the best response to polymerflooding with the wells on the outside of the project area showing very little response to polymer injection.
Enhanced Oil-Water Separation—The Performax Coalescer
Authors: Rehm S. J. , Shaughnessy R. J. 
Published: December 2007

ABSTRACT
The Freewater Knockout (FWKO) has been the basic oil field standard in oil-water separation for many years; The PerformaxR Matrix Plate Coalescer is an improved enhanced oil-water separator which satisfies the oil producers' desire for a simple, efficient separator. Sizing and case history information is reviewed. Results from light gravity paraffinic oils to heavy gravity asphaltic oils are detailed. The Performax Coalescer with improved oil, gas, and water quality is becoming the new industry standard for oil-water separation.
Stimulation Techniques in the Red Fork Formation in the Anadarko Basin
Authors: Brunette P. T. 
Published: December 2007

ABSTRACT
This paper presents the results of fracture stimulation treatments on the Red Fork formation in the Anadarko basin. All wells studied are located in Roger Mills and Custer counties of Oklahoma (Fig. 14). Only data for which valid production information was available are included.
Fracturing techniques and their results using five different stimulation fluids are examined; cross-linked water base, gelled water (non cross-linked), gelled diesel, gelled carbon dioxide, and foamed carbon dioxide with water as the liquid phase. Three types of propping agents have been used in various grades in conjunction with the above stimulation fluids; sand, intermediate strength proppant and high strength sintered bauxite.
A discussion of various treatment parameters and their possible overall effect on the production results are presented.
Ultra-High Sand Concentration in Hydraulic Fracturing— A Case History
Authors: Shah S. N. , Smith D. R. , Donaldson D. E. 
Published: December 2007

ABSTRACT
Because of their success, ultra-high sand concentration (USC - a commonly used field acronym) treatments have become very popular in Oklahoma. To-date, more than 50 wells have been completed using USC treatments.
This paper presents the state-of-the-art on USC in hydraulic fracturing with field data and documented results. Case histories of the two representative wells selected from different areas of the state, are discussed in detail in the paper. Well production data before and after the USC treatments, are compared. A detailed USC job design procedure is also outlined. Furthermore, some suggestions are made to help the reader in designing and conducting USC treatments.
Improved Well Stimulation With Resin-Coated Proppants
Authors: Sinclair A. R. , Graham J. W. , Sinclair C. P. 
Published: December 2007

ABSTRACT
Resin-coated proppants improve well stimulation results by preventing flowback, or fracture evacuation, near the wellbore, a phenomenon that effectively "decouples" the wellbore and the productive formation. In addition, the deformable coating protects the resin-coated proppants from crushing and helps resist embedment in softer formations. The tough coating is chemically inert in crude oils, brines, and most acids. The resin-coated materials work best under actual down-hole conditions since the closure stress and temperature help lock the materials in the fracture for the 1ife of the well.
This paper reviews case histories from four wells in which resin-coated proppants were used. In addition, simple lab tests of the resin-coated proppants in an API crush cell confirm their excellent properties and potential. Together, these results show the need for resin-coated proppants in many types of wells. In many ways they act as "ideal" proppants that can be economically justified over uncoated proppants.
Production System Optimization for Natural Flowing Water Drive Wells
Authors: Chu M. H. , Evans R. D. 
Published: December 2007

ABSTRACT
This paper presents the results of a computer study which leads to the optimum design of a production system for flowing wells subjected to a natural water drive. The results presented consist of a series of graphs which are derived from an analysis of the inflow performance relationships, vertical lift performance, choke performance, horizontal flow performance, and the thermodynamic conditions of the surface conditioning equipment such as separator and flow lines.
The Hagedorn and Brown correlations and the Beggs and Brill correlations are utilized to determine pressure drop for vertical lift and horizontal flow performance for multiphase flow. Using these correlations and assuming a flow rate and starting from the separator, pressure losses are calculated along the flowline to the wellhead, across the choke, and down the tubing to the tubing intake. Output from the analysis results in an optimized system design which maximizes production for a set of reservoir conditions and surface contraints.
An example well problem are presented which demonstrate the applicability and versatility of the computer analysis. An analysis is also presented to assess the sensitivity of various parameters upon well performance. Such parameters as flowline size, separator temperature and pressure, choke size, tubing size, water oil ratio, gas oil ratio, productivity index, oil gravity and fluid slippage are considered in the sensitivity analysis.
The results of this analysis and the data presented provides the production engineer with a technique for designing a system which will optimize production from a given well. The approach is general in that the outputs from the analysis provides the engineer with a set of curves and graphs to assist in making a final decision concerning a specific well or group of wells.
Waste Water Disposal Above Fracture Gradients in California
Authors: Doscher T. M. , El-Arabi M. A. 
Published: December 2007

Abstract
In order to permit economic operation of Placerita Oil Field leases, a request was made of the Division of Oil and Gas of the State of California for a waiver on the regulation limiting the sand face pressure of water disposal operations to a value less than the apparent frac gradient. This is an account of the justification presented to the DOG for seeking a variance from the regulations, the DOG's positive response, and subsequent field operations.
A Laboratory Study of Heavy Oil Recovery with CO2 Injection
Authors: Sankur Vega , Emanuel A. S. 
Published: December 2007

Abstract
Recovery of a California heavy oil by CO2 injection was investigated using laboratory core floods and computer simulation. CO2 drive and huff-n-puff techniques were studied for tertiary recovery of a 14° API gravity, 3000 cp viscosity oil from a waterflooded core. The core material was poorly consolidated sandstone under simulated reservoir stress.
At 1250 psia, CO2 drive recovered up to 54% of the remaining oil in place (ROIP), the recovery increasing with increasing slug size. The CO2 utilization factors also increased with CO2 slug size, ranging from 1.1 MSCF/BBL to 8.0 MSCF/BBL. The addition of 18% N2 into CO2 at this pressure resulted in earlier gas breakthrough and lower recoveries compared to pure CO2 injection.
At 750 psia a 3.0 PV slug of CO2 recovered 20% of the ROIP, reflecting lower recoveries at lower pressures. The use of small slugs improved CO2 utilization also at this pressure with an accompanying decrease in overall recovery to 16% of ROIP.
The CO2 huff-n-puff technique was tested on the same system at 1250 psia pressure. The first cycle recovered 6% of the ROIP with a CO2 utilization factor of 11 MSCF/BBL. The second cycle recovered an additional 3% with a utilization factor of 33 MSCF/BBL.
The core floods were simulated using a compositional simulator with a three-component Peng-Robinson model for fluid properties. The simulator predictions agree qualitatively with the experimental results. Calculated saturation profiles through the core are presented.
Well Completions in the Beta Field, Offshore California
Authors: Bruist E. H. , Jefferis R. G. , Botts T. M. 
Published: December 2007

ABSTRACT
The heavy oil reservoir in the Beta Field, Offshore California is thick (up to 1200 feet gross), unconsolidated, consists of nine distince sand intervals, and lies at a shallow depth. In order to economically develop the field from two platforms and be able to waterflood, the development wells must (1) be highly deviated with an ‘S’ shaped profile, (2) have isolated multi-zone completions designed with the capability to selectively inject or produce any combination of zones, and (3) produce virtually sand-free because of the use of electric submersible pumps for artificial lift.
To meet these requirements, new completion techniques were developed. This paper reviews the overall completion sequence starting with primary cementing and zonal isolation, through perforating and perforation cleanup, and finishing with the inside casing gravel packing and gravel pack logging. The new techniques have proved expedient and successful, with 40 producing wells containing a total of 152 individual zones completed as of December, 1982.
Interference Analysis for Wells Produced at Constant Pressure
Authors: Ehlig-Economides C. A. , Ansari J. A. 
Published: December 2007

ABSTRACT
Although there are numerous techniques for analyzing pressure interference effects for constant rate wells, the analogous rate transients due to interference among constant pressure producers have never been investigated in detail. The transient pressure behavior resulting from interference effects among wells produced at constant rates can be determined in a straightforward manner using the principle of superposition in space. For constant pressure producers, the flow rates are continuously changing. Hence, the pressure interference among constant pressure wells cannot be determined in the conventional way.
In this study, the rate interference among constant pressure production wells is modeled using the diffusivity equation. Pressure distributions in the reservoir for both constant pressure and constant rate couplets were obtained. The two are qualitatively similar and exhibit a similar zone of zero pressure gradient, which confirms the existence of an apparent no-flow boundary between any two constant pressure producers analogous to the one that is known to exist between wells flowing at constant rate. Results also show that a nearby fault boundary can be detected in a drawdown well test as the doubling of the slope of the semi-log straight line produced when the reciprocal of the flow rate is graphed versus the log of time.
Another principal function of modern well testing is to evaluate the formation anisotropies. The method given by Ramey for the constant rate environment does not fully hold for the constant pressure setting. Therefore, a new method for evaluating directional permeabilities has been developed.
To demonstrate the theory in application, example problems have been worked explaining and emphasizing the practical applications of the new techniques.
The Test and Evaluation of a High-Horsepower Cable-Suspended Submersible Pump in a Prudhoe Bay Well
Authors: Drysdale C. E. , Brookbank E. B. 
Published: December 2007

ABSTRACT
A test and evaluation project of the cable suspended pumping system (CSPS) was started in mid-1979 by Sohio to assess a possible alternative method to gas lift in some limited areas of Prudhoe Bay.
The major objectives of the project concerned the applicability of an unproven artificial lift system to a low temperature environment and the high rate, pressure, and GOR of Prudhoe Bay oil wells. The culmination to the conceptual planning was an eight-month field test in Well A-1 during which time three ESP change-outs were performed.
A major result from the field test evaluations concerned cable slippage down through the wellhead cable pack-off. This was attributed to both the cable material response in the large temperature range experienced and the design of the cable retention mechanism.
The hands-on experience provided representative data for state-of-the-art assessment of CSPS. This paper summarizes the technical evaluations of this prototype installation and identifies the work necessary to complete the development for reliable, commercial application in low temperature areas.
The Role of Reservoir Lithology in Design of an Acidization Program: Kuparuk River Formation, North Slope, Alaska
Authors: Boyer R. C. , Wu Chia-Hsin 
Published: December 2007

ABSTRACT
Sandstone lithologies in the Lower Cretaceous Kuparuk River formation were tested to study formation damage during acid treatments. Two lithologies were analyzed before and after acidization: 1) a glauconitic sandstone cemented by siderite, and 2) a sandstone containing clay minerals with minor carbonate cements. These samples were treated with hydrochloric acid containing iron-chelating and silt-suspending agents, with hydrofluoric acid, and with fluoroboric acid, all at reservoir pressure and temperature. Formation damage was evaluated by scanning electron microscopy (SEM), X-ray diffraction, petrographic analyses, and acid effluent analyses. Carbonate cement and clay mineral content were critical factors that governed the extent of formation damage.
Hydrofluoric acid is commonly used to stimulate sandstone reservoirs. However, results showed that this acid caused formation damage in both Kuparuk River lithologies. SEM examination of siderite-cemented sandstones after treatment showed abundant iron-rich and poorly crystalline fines dispersed in pores. These mobile fines included partially dissolved siderite, iron precipitates, and colloidal silica. In sandstones with clays, hydrofluoric acid partially dissolved and released clay particles which could plug pore throats during production. Hydrochloric acid with iron-chelating and silt-suspending agents gave the best results in siderite-cemented sandstones. This acid prevented iron released from siderite and glauconite from forming precipitates and cleaned up the wellbore. Fluoroboric acid was the best treatment in sandstones containing clay minerals. SEM examination showed that this acid cemented undissolved clay particles to framework grains. Thus, pore throats remained open.
Selection of the acid treatment compatible with reservoir lithology will minimize formation damage and lead to increases in production.
Use of Lumped Parameter Modeling for Geothermal Engineering
Authors: Castanier L. M. , Brigham W. E. 
Published: December 2007

Abstract
The theory and algorithm are presented for the implementation of a lumped parameter approach for geothermal reservoir simulation in the early stages of the development of a geothermal field. The model can be applied to all types of geothermal systems: all-liquid, all-steam, or two-phase.
This paper focuses on examples of utilization of a simple lumped parameter model in three cases:
The model is used to verify the validity of experimental results obtained from a bench-scale model and to calculate the heat transfer parameters of the experimental apparatus. In Ref. 1, a brief comparison was made on the East Mesa reservoir between lumped parameter results and the results obtained by Morris and Campbell using a three-dimensional finite differences simulator. We will use this study to show the use of a lumped parameter approach to give focus to the important variables prior to more complex simulation efforts. Production and pressure histories of the Cerro Prieto geothermal field were assembled from field data. The model was then used to perform sensitivity studies on reservoir size, porosity, aquifer recharge rate and temperature of the recharge fluid for the Unit 1 and 2 production area. Two types of depletion schemes were investigated; in the first, the reservoir remains in liquid phase; in the second, the reservoir becomes two phases at an early point of its history. A satisfactory match of the history of the field has been obtained only for the second case.
The problems encountered during the application of the lumped parameter technique to each of these examples are discussed; also, limitations of this approach are mentioned.