bluuebunny/crossref_metadata_2025_split huggingface dataset:
Designing a Produced Water Re-Injection Program in Bekapai Field
Authors: Singh Kalwant 
Published: December 2007

Abstract
Production of oil & gas has very big influence to mankind civilization but the excessive generation of produced water in mature fields as a by-product may have bad impact to environment. Pollution of surface water supplies or fresh water aquifers has become a serious concern in recent years. It is therefore an obligation upon the industry to handle the produced water and disposed it responsibly. This concern has focused attention on produced water re-injection into underground formation as a promising method to discharge oilfield water without polluting potable water supplies.
As refer to regulatory guidelines, injection well for produced water disposal must be operated so that the pressure during injection does not initiate new fractures or propagate existing fractures in the confining zone adjacent to the sources of drinking water, which could damage the receiving layer or cap rock. In order to achieve that purpose, the paper describes planning on operational aspects regarding daily activity/practical operation, which are essential to the successful of water injection project by using developed software. Operational aspect especially includes working pressure along the injection system, estimated formation fluid pressure as function of cumulative injected water, estimated fracture pressure and its relation to proposed injection rate. Operational window for injection must be developed to determine the range of allowable injection pressure and its relationship with the proposed injection rate.
The paper also describe a method to determine the life time of each proposed injection well which is the compilation from the result of operational design analysis and reservoir pressure builds up data from simulation results. This study is very useful to make injection programs and scenarios to extent the injection lifetime (e.g. scenario to add new injector wells).
Construction of the Hondo Field Pipelines by the Reverse J-Tube Procedure
Authors: Matthews Jamie F. , Cunningham Gerald R. , Hofferber John E. 
Published: December 2007

ABSTRACT
During the summer of 1980 three pipelines were constructed between the Hondo Platform, located in 835 feet of water, and the Hondo SALM, located approximately 1-1/2 miles away in 500 feet of water. Figure 1 shows the Hondo Platform, SALM, Offshore Storage and Treating (O.S.&T.) vessel, and pipelines. These pipelines, ranging from 6-inch to 12-inch in diameter, were installed by the reverse J-tube procedure, a technique developed by Exxon especially for construction of deepwater pipeline systems. The technique may also be cost effective in certain shallow water applications.
Pipe Flow Rheometry: Rheological Analysis of A Turbulent Flow System Used for Cement Placement
Authors: Bannister C. E. , Benge O. G. 
Published: December 2007

ABSTRACT
Determination of the Theological behavior of cement slurries is essential for proper evaluation of flow rates required to achieve optimum mud removal. Rhe-ological characteristics of cement slurries and spacer fluids have been evaluated using pipe-flow rheometry. By this method, rheological measurements were obtained by monitoring the pressure required to pump a fluid through either a pipe or an annular gap.
The results suggest that the rheological properties of cement slurries are modified by apparent "slip" at the pipe surface making the onset of turbulence more difficult to achieve. This wall "slip" is attributed to particle migration away from the pipe surface when the fluid is sheared. Due to this anomalous behavior, a three-parameter mathematical model is required to evaluate pump rates required for the onset of turbulence.
Use of pipe-flow rheometry has resulted in the design of a turbulent flow fluid which is "rheology-con-trolled" to permit easy calculation of the critical pump rate. The value of turbulent flow in cement placement is demonstrated by field evaluation of several wells in which production liners and intermediate casings have been successfully cemented into place using a "rheology-controlled" spacer fluid ahead of the cement slurry. To insure "rheology-controlled" behavior, the spacer fluid exhibits excellent fluid-loss control to inhibit rheological changes detrimental to good mud removal.
Pipe-flow rheometry has been instrumental in characterizing the factors responsible for turbulent flow behavior. Proper rheological evaluation coupled with fluid-loss control behavior will give the necessary information for optimizing cement placement.
Cleanup of Water-Based Kill-Pills in Laboratory-Simulated Perforation Tunnels During Flowback
Authors: Suri A. , Sharma M. M. 
Published: December 2007

AbstractKill-pills and completion fluids form internal and external filter cakes in perforation tunnels. A laboratory study on the cleanup of water-based kill-pills in lab-simulated perforation tunnels is presented. Flow initiation pressures (FIP) and return permeabilities are measured at constant pressure during flowback.A sized calcium carbonate kill-pill and a bentonite mud are tested on rocks ranging in permeability from 25 md to 1500 md with various lab-simulated perforation tunnel dimensions. Both single-phase and two-phase experiments are conducted to better understand the factors affecting the cleanup of the perforation tunnels.The FIP values are found to range from 2 to 15 psi depending upon the perforation tunnel dimensions. The FIP values are small (&lt; 4 psi) in large diameter perforations and the external filter cake is formed only along the walls of the tunnel. These small FIP values in large diameter perforations are comparable to the FIP values obtained for open-hole completions with no perforations. However, in small diameter perforations, large FIP values are obtained, and the external filter cake is found to completely plug the tunnels. Both internal and external filter cakes determine the FIP in perforations with small diameter; however, the FIP in large diameter perforations is mostly determined by the internal filter cake. Pressure gradients up to 20 psi / inch and flowback rates up to 0.3 bbl/day/perforation are found to result in approximate skin factors &lt; 2 for all simulated perforations which had an overbalance of 100 psi.
Simplified Method for Characterizing Fractured Carbonate Media
Authors: Pérez-Rosales C. , Luna E. , Serrano E. 
Published: December 2007

AbstractQuantitative characterization of fractured carbonate rocks is of interest for several reasons: first, because naturally fractured carbonate oil reservoirs are among the most important in the world; second, because fluid flow through the pore system depends on the internal geometry of the rock; and, third, because numerical simulation of such reservoirs require reliable values of matrix porosity, fracture porosity, and block size.Naturally fractured reservoirs are complex systems whose flow properties are not well understood. From the fluid transport viewpoint, fractured carbonate reservoirs can be considered to consist of two basic components: matrix blocks and fracture network. Matrix blocks are characterized by their low fluid conductivity, and their main function is to storage fluids, whereas the fracture network is composed of highly conducting channels.This paper describes a simplified method for determining matrix and fracture porosities of carbonate media, as well as block size. The method makes use of total interconnected porosity and formation resistivity factor data. Of fundamental importance to the method is the fact that, in the case of fractured carbonate media saturated with a conducting fluid, the conductivity of the fracture network is much greater than that of the matrix blocks, so that, for practical purposes, the latter can be considered as negligible.For illustration purposes, an application to a real case is presented. To this end, use is made of two procedures, one for fracture porosity and the other for block size. A step by step description is given for each procedure. It is considered that the simplicity of the procedures make the methodology an attractive tool for the characterization of carbonate fractured reservoirs.
Thermal Injection Well Falloff Testing
Authors: Walsh John W. , Ramey H. J. , Brigham W. E. 
Published: December 2007

ABSTRACT
A study was conducted to find field case histories of swept volume determination from pressure transient tests at an injection well. In an earlier study, a pressure transient model of a two-region reservoir was solved analytically and it demonstrated that in principle, both the permeability-thickness and also the swept volume of both regions may be determined. From the model, a typical falloff curve consisted of an initial semilog straight line, a transition period, and finally, a second semilog straight line. The transition period was found to contain a pseudosteady-state Cartesian straight line whose slope was related to the swept volume. Several sets of field test data were examined to verify the existence of the Cartesian straight line.
In order that the swept volume may be calculated from the slope of the Cartesian straight line, the average reservoir pressure and temperature in the swept zone must be estimated. The average pressure is the early-time flattening of the pressure curve on a semilog graph. The average temperature can be estimated from the pressure for steam injection, but requires calculation for combustion. One method involves a heat balance which includes both the heat generated by combustion and heat loss to overburden. Knowledge of the swept volume permits calculation of important economic parameters including the fuel concentration in a combustion test and heat loss in a steamflood.
Several case histories are presented from both in-situ combustion and steamflood projects. An investigation for each case history shows the information that may be obtained from pressure transient tests. Pressure transient testing of the injection well may prove useful in evaluating and controlling the performance of thermal recovery projects.
Application of Relative Permeability Modifiers to Control Water Cut Following Hydraulic Fracturing in Western Siberia Oilfields—Russian Case History Study
Authors: Borodin E. G. , Vakhroushev P. E. , Stolyarov S. M. , Kalfayan L. J. 
Published: December 2007

Abstract
Due to geological characteristics and low permeability of Western Siberia hydrocarbon reservoirs, hydraulic fracturing is the most effective method for improving hydrocarbon production. During recent years the massive fracturing treatments in this area have led to a reduction of well candidates for this type of production enhancement technique. Currently the majority of selected wells for fracture stimulation are considered "risky" because of significant water cut increase after stimulation. The question arises – How to reduce water production while enhancing oil production?
This paper reviews 26 case histories exemplifying the use of Relatively Permeability Modifiers (RPM) in hydraulic fracturing to enhance oil recovery and control water production. Also results of laboratory studies are included to support the RPM-fracturing concept and placement techniques.
A Model for Gas Coning and Rate-Dependent Gas/Oil Ratio in an Oil-Rim Reservoir
Authors: Mjaavatten Are , Aasheim Robert , Saelid Steinar , Gronning Oddvar 
Published: December 2007

Abstract
In oil rim fields a thin oil layer lies between an aquifer and a gas cap. Oil may be produced from such fields using horizontal wells. Production will lower the local gas/oil contact near the well in a process called gas coning (or more accurately, cresting). After gas breakthrough, the gas/oil ratio (GOR) from the well may vary strongly with the production rate. The ability to predict this dependency is essential for production optimisation for such fields.
We have developed a mathematical model that can predict gas coning behaviour and the resulting rate dependent GOR with a surprisingly high degree of accuracy over periods of several months or more. We combine a dynamic model that describes the essential reservoir behaviour with a highly simplified description of the interaction between the well and the surrounding reservoir. The full model has three adjustable parameters that allow us to fit the behaviour to individual wells, using historical oil and gas production rates. The model forms the basis of the GORM (Gas/Oil Ratio Model) computer program that since early 2003 is in regular use for production planning and optimisation at the Troll field. We have also tested the model on wells in other fields, with encouraging results.
Fracturing Treatments of Openhole Horizontal Wells in Western Siberia
Authors: Brovchuk A. V. , Diyashev I. , Lipyanin A. V. , Grant D. , Oussoltsev D. , Butula K. K. 
Published: December 2007

Abstract
In Western Siberia, there is a number of open-hole horizontal wells completed with un-cemented predrilled liners. While many of these wells produced as expected, some wells with horizontal section lengths between 500 to 1100m (effective lengths from 400 to 900m), were producing significantly lower than the offset verticals wells that had been hydraulically fractured with proppant. Decline curve analyses of these under producing wells indicated either high skin value or a limited producing horizontal interval.
Various attempts to increase the production by cleaning up the horizontal section of the wellbore (such as acidizing with CT, implosion treatment etc.) showed only small incremental in PI but did not solve the problem of reducing the skin to zero or lower. Technical limits and large financial and operational expenditures, as well as associated production losses made these types of treatments unattractive.
Detailed analysis of the formation and production data, selection of top-priority candidate wells with employment of technically sound frac designs allowed the operator to implement propped fracturing treatments as a stimulation method in these horizontal open-hole wells. As a performed risk analysis of the stimulation operations was deemed acceptable, hydraulic fracturing treatments were initiated and to date, the 19 propped fracture treated open-hole horizontal wells in Noyabrsk region of Western Siberia (Sugmutskoe and Romanovskoe field) have shown productivity index [PI] increases between 2 to 4.5 folds. This compares favorably to offset vertical fractured wells with S = -5 (1.8 – 3.8 folds).
This paper describes the unprecedented integrated approach in hydraulic fracturing treatments of horizontal open-hole wells with un-cemented predrilled liners as one of alternative completion methods that may be used in horizontal field development projects.
Prop Transport in Vertical Fractures
Authors: Clark Peter Edward , Manning Francis Scott , Quadir Jamal A. , Guler Nihal 
Published: December 2007

ABSTRACT
The subject of prop transport in vertical fractures has been much discussed in the literature in the past five years. Yet, there are many questions that remain unanswered. Probably the most difficult question to answer involves particle transport by cross-linked gels. The major problem encountered in studying particle settling in cross-linked fracturing fluids is the extremely slow settling velocities. This limits the type of experimental apparatus that can be used to closed systems with long particle residence times. The low settling velocities coupled with the difficulty of obtaining good rheological data makes the development of mathematical correlations for the data difficult.
In this study, two different experimental models have been used to obtain particle settling data. One model consists of a parallel plate apparatus in which the shear on the fluid is provided by a moving belt and the other consists of a concentric cylinder device similar to that described by Novotny (SPE 6813). Both of these models are capable of providing adjustable shear rates and long particle residence time necessary for data collection. Data will be presented for both cross-linked and uncross-linked fluids. The viscosities and degree of cross-linking have been varied in order to detect the influence that cross-linking has on particle settling velocities over and above the contribution that cross-linking makes to the viscosity.
Remediation of Production Loss Due to Proppant Flowback in Existing Wellbores
Authors: Nguyen Philip D. , Stegent Neil A. , Ingram Stephen R. 
Published: December 2007

Abstract
This paper presents the results of experimental study and field case histories of a remedial treatment technique using a low-viscosity consolidating agent placed into the propped fractures by coiled tubing (CT) or jointed pipe coupled with a pressure pulsing tool. The treatment fluids are designed to provide consolidation for previously placed proppant near the wellbore without damaging the permeability of the proppant pack. The consolidation treatment transforms the loosely packed proppant in the fractures and the formation sand close to the wellbore into cohesive, consolidated, yet highly permeable packs.
Laboratory flow testing indicates that the proppant pack in a fracture model under closure stress required low-strength bonds between proppant grains to withstand high production flow rates. Field case histories are also presented to discuss treatment procedures, precautions, and recommendations for implementing the treatment process. One major advantage of this remedial treatment method is the ability to place the treatment fluid into the propped fractures, regardless of the number of perforation intervals and their lengths without mechanical isolation between the intervals. The fluid placement efficiency of this process makes remediation economically feasible, especially in wells with marginal reserves.
Linear Gas Drives in High-Pressure Oil Reservoirs Compositional Simulation and Experimental Analysis
Authors: Auxiette Gerard , Chaperon Isabelle 
Published: December 2007

ABSTRACT
This paper presents an analysis of the compositional process involved in the displacement of oil by high pressure gas injection as observed in laboratory experiments. Such an analysis is necessary in order to transpose these results to a field-wide scale for EOR projects.
Therefore a two-fold compositional tool has been developed: The first function handles the Peng and Robinson equation of state to describe phase equilibria of multicomponent hydrocarbon mixtures. Based on thermodynamic considerations it computes either frontal or rear dynamic miscibility pressure as well as direct miscibility pressure of a gas/oil system.The second function simulates linear displacement of oil by gas involving compositional exchanges between phases (also based on P.R. equation of state) and their effect on flow parameters.
Results of this compositional model are checked against laboratory experiments carried out on a field crude oil with three possible injection gases.
This model yields a better understanding of various types of non-equilibrium gas drives and enhanced recoveries related to compositional transfers and mobility variations.
A useful application is to select the most appropriate gas to be injected into a given field under reservoir conditions or after some depletion. It also shows how the notion of gas/oil relative permeability curves should be reviewed if a black-oil model is used to simulate flow of non-equilibrium fluids.
Miscible Gas Enhanced Oil Recovery Economics and Effects of the Windfall Profit Tax
Authors: Bloomquist Charles W. , Fuller Keith L. , Moranville Michael B. 
Published: December 2007

ABSTRACT
The profitability of miscible flooding in a hypothetical target oilfield is examined. The major costs, including Windfall Profit Tax, are identified and their relative importance are discussed. The sensitivity of profit to important physical and economic variables is evaluated and discussed, including variance in oil recovery, oil price, injectant requirements, injectant cost, and capital requirements. Economic sensitivities to important development and operating decisions such as timing. spacing, slug size, and gas recycling are also analyzed. The Windfall Profit Tax (WPT) as it applies to gas miscible EOR projects is reviewed. The effect of WPT on each of the various project cases is analyzed and the effect of reduced WPT on remaining production from existing operations is evaluated. Tax implications are compared for integrated vs. "independent" controlled projects and the alternative of expensing vs. capitalizing tertiary injectants is also evaluated. The impact of the Net Income Limitation in reducing WPT during early and late project life is determined and discussed.
Investments and the Energy Price Revolution
Authors: Roberts Martin C. 
Published: December 2007

ABSTRACT
The quantum jump in crude prices which we have expoerienced over the past seven years has had an extraordinary impact on the economic, social and political well-being of the world. That impact is evidenced in the way in which investors perceive the equity markets, a perception that now appears to oscillate between euphoria and dischantment over a relatively short period of time.
The reason for this short-term "bullish and bearish" attitude appears to be the uncertainty brought about by (1) the impact of the magnitude of the crude price increases on existing technologies, and (2) the change in supply/demand relationships for the crude itself.
With regard to the former, rapidly increasing crude oil prices have made the western world's plants and processes essentially obsolete, an obsolescence due to their energy intensive processes and configurations, which were designed to run on relatively inexpensive fuels. Consequently, we are now witnessing the refinancing in the U.S. of its industrial plant, (e.g., revamping of refining facilities, retooling of automobile manufactturing, and a potential emergence of a synfuel industry.) Obviously, the uncertainties associated with the timing, financing and technology of these changes raise serious questions in the minds of investors cocerning the degree to which these investments will be capitalized in the market place.
The second issue of uncertainty has to do with the crude oil supply/demand relationships, which have changed substantially over the past seven years. Classic supply/demand relationships do not necessarily hold for a political, price administered commodity like crude oil. The international oil trade has undergone considerable structural changes so that today about 80% of world crude reserves and 20% of the volume sold are controlled by national oil companies--just the reverse of 10-15 years ago. Consequently, those who are forecasting surplus conditions and who are advocates of the "glut thesis" are failing to come to grips with the fact that the incremental worldwide crude supplies are derived from a portion of the world in which the supply lines are long, tenuous and subject to interruption for reasons that can be economic, political or social. The high degree to which the world depends upon these insecure, expensive incremental crude supplies seems to preclude a forecast of long term surplus supplies and downward price pressures.
The investment implications of insecure, expensive foreign crude supplies coupled with an attempt by the western industrialized world to modernize its plant appear to involve uncertainties which span the entire spectrum from the geopolitical aspects of the international oil trade to commercialization of emerging technologies. In the final analysis, it seems that. the 1arge, secure, albeit costly, U. S. technological and resource base would encourage long term investments in those domestic industries that will benefit from an expanding natural resource base and/or emerging technological base.