bluuebunny/crossref_metadata_2025_split huggingface dataset:
A Different Approach to Solving Mud-Related Hole Problems
Authors: Chamberlain D.E. 
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.
This paper was prepared for the Improved Oil Recovery Symposium of the Society of Petroleum Engineers of AIME, to be held in Tulsa, Okla., March 22–24, 1976. 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 PETROLEUM ENGINEERS JOURNAL is usually granted upon request 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 discussion may be presented at the above meeting and with the paper, may be considered for publication in one of the two SPE magazines.

Abstract
In this paper is discussed a method of analyzing and solving hole problems based on data received from mud check sheets and annular flow calculations. Included is a basic review of the eleven functions of mud required to drill the hole to desired depth and size at minimum costs. Several tests and system checks to insure that a selected mud system is fulfilling its functions are included.

TEXT
Matching annudar flow (hydraulics) programs with mud programs is very valuable in obtaining a successful solution to hole problems. How many times, in spite of remedial action, does a hole problem persist, or another problem arise shortly after such action has been taken? Analysis of the problem may be based on annular flow, which is the science of fluids in flow, or on drilling muds, or a combination of both. Analyzing both these data will help solve the problem itself rather than treating only the symptoms resulting from the problem.
The following is a basic review of the functions of a drilling mud and how these functions are determined from mud sheets and annular flow calculations. To begin, the mud should be accurately tested to determine its composition and chemical properties. Mud is composed of a liquid phase, active solid phase, and inert solid phase. The liquid phase may be freshwater, saltwater, or oil which may contain various soluble or partially soluble chemicals that are considered part of the composition. Active solids are usually commercial clays used as the primary source for rheological and filtration control, and hydratable clays and shales from drilled formations. They are chemically treated to control the properties of the drilling mud.
How To Enhance the Recovery of Intermediate Components of an Extremely Volatile Oil
Authors: Palasthy Gy. , Papp I. , Lakos B. , Tromboczky S. 
Published: December 2007

Abstract
An enhanced recovery process suited to a hydrocarbon reservoir containing extreme quality crude oil is presented in the case history. At the initial pressure and temperature conditions (pi=169 bars and ti= 92 °C), the oil reservoir volume factor is: Boi=3.94 m3/m3, the dissolved gas content: Rsi=712 m3/m3 and the specific gravity of the crude only ρ =0.728 t/m3 (63 API).
The reservoir has been produced since 1984 and Eo= 37 % recovery has been reached, while the pressure has declined only by 5 % because of the active water drive. The further production strategy was elaborated with a 3-D, full field composition simulator by an integrated team between 1996-98.
The forecast calculations show that Eo=48 % final recovery can be reached for the individual components in the reservoir with strong water drive. For further recovery enhancement, the best dissolved - both from technological and technical aspects - seemed to be a dry gas injection process which would cause 10-13% additional recovery in the C3-C6 components of the crude oil.
Influence of Nonuniform Initial Pressure Distribution in Well Test Data
Authors: Sampayo-Trujillo Antonio , Camacho-Velázquez Rodolfo 
Published: December 2007

Abstract
Most of the procedures available in the literature for well tests analysis assume a uniform initial pressure distribution. In this paper the influence of a non-uniform initial condition in pressure data is presented.
Several solutions, which consider a non-uniform initial distribution and different conditions at the inner and outer boundaries, are presented. These solutions were obtained by using a combination of Laplace transformation and Green's function methods. Integral equations relating the well response to the initial distribution function are obtained. These equations, which represent inverse problems, are solved recursively by using Backus and Gilbert solution.
Numerical experiments of the pressure response in homogeneous and naturally fractured reservoirs with different initial pressure distributions are presented. The theory and numerical results are compared and found good agreement demonstrating the applicability of the proposed method.
For radial systems it is found that the semilogarithmic straight line is not generally evident during the transient period. Also during the boundary dominated flow period, with no-flow outer boundary, it is found that an additional pressure drop is present for the case of a non-uniform initial distribution. An expression for this additional pseudo-skin is provided.
Complexity of Well Testing Analysis of Naturally-Fractured Gas-Condensate Wells in Colombia
Authors: Pinzón Claudia L. , Chen Her-Yuan , Teufel Lawrence W. 
Published: December 2007

Abstract
Reservoir management is difficult for several gas fields in the flanks of the fold-thrust belt of the Eastern Cordillera of the Middle Magdalena Valley, Colombia. Technical complicating factors include (i) complex geology (faulting, naturally fractured), (ii) high tectonic stresses (&gt; 1.0 psi/ft), (iii) high-angle formation dip (&gt; 60°), (iv) overpressure (&gt; 1.0 psi/ft), and (v) gas condensation. Due to the unusual stress/tectonic environment, a potential impact to reservoir performance is the stress-sensitive permeability (permeability reduction-rebound induced by fluid withdrawal-injection). Interpretation of well testing thus is challenging because of the combined effects from the above factors.
This paper presents an analysis of a field isochronal test. The effect of stress-sensitive permeability on well test response is emphasized through numerical simulations. Other factors complicating the well-test interpretation are also discussed. Pressure derivative analysis is shown to be very useful in identifying the permeability variation. The logarithmic slopes basically reflect the combined variations of permeability, producing thickness, flow rate, and fluid properties. Natural fracturing, gas-condensation, high gas rates, and stress-sensitivity permeability will contribute to the changing slopes of pressure response. The impacts are essentially reflected by the magnitudes of near-wellbore skin and reservoir permeability. Guidelines useful in identifying stress-sensitive permeability from well testing are proposed.
Three-Phase Discrete Flow Network Simulation Matches Vertical and Horizontal Completion Efficiency
Authors: Button P. M. , Wadleigh E. E. 
Published: December 2007

Abstract
An innovative approach has been used to model flow through discrete fracture networks in a massive carbonate reservoir in order to understand and predict performance of vertical and horizontal well completions. This approach focuses on completion effectiveness and the influences that fractures have in a three-phase gravity influenced flow system. The model is set up as a dual porosity, dual permeability simulation of a discrete fracture network of high permeability grid blocks capable of modeling three-phase flow. This model reveals the dominant factors controlling well life cycle performance demonstrated in the Yates Field Unit
Natural fracture networks dominate flow throughout the reservoir with added economic significance to completion efficiency. Therefore 3D discrete fracture network (DFN) models based on connected-fracture orientation from FMI logs and flow surveys have been used as a basis for constructing the 3-phase simulation grid. The differences in mobility between the three phases result in abnormally shaped gas-oil and water-oil contacts as drawdown is applied. As the fracture oil column depletes, oil mobility reduces with the decrease in effective fracture connection to the outlying oil column. This loss of oil mobility through phase dis-connection in flow conduits has not been the focus of prior studies. The simulator has successfully generated production profiles similar to those observed in field performance data. This wellbore simulation has been used to develop a strategy for optimal completion performance and placement.
Applicability and Rate Sensitivity of Several Up Scaling Techniques in Fractured Reservoir Simulation
Authors: Talukdar M. S. , Banu H. A. , Torsæter O. , Kleppe J. 
Published: December 2007

Abstract
This paper presents the applicability/validity and rate sensitivity of several conventional up-scaling techniques in fractured reservoir simulation. Three different models have been developed and simulated using Kyte and Berry, Pore Volume Weighted, Weighted Relative Permeability, and Stone type pseudos at different rates and with different oil-to-water viscosity ratio.
From the results it can be concluded that these techniques may be used in fractured reservoir simulation in order to reduce number of simulation grids as well as to synthesize details of small-scale fluid mechanics and reservoir heterogeneity. They may or may not be rate sensitive depending on the model type.
Core Analysis Techniques, Case Histories and Interpretation of Data For the Rocky Mountain Region
Authors: Harris James D. , Keelan Dare K. 
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.
This paper was prepared for the Improved Oil Recovery Symposium of the Society of Petroleum Engineers of AIME, to be held in Tulsa, Okla., March 22–24, 1976. 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 PETROLEUM ENGINEERS JOURNAL is usually granted upon request 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 discussion may be presented at the above meeting and with the paper, may be considered for publication in one of the two SPE magazines.

Abstract
Reasons are presented for securing core analysis data that furnish porosity, permeability, residual fluid saturations and lithology. Types of core analysis are briefly reviewed. Changes in in-situ fluid saturations resulting from flushing during coring and fluid expansion during transport of the core to the surface are discussed. Precautions in core sampling, handling, packaging and preservation are briefly reviewed. Interpretation of data, using actual case histories of formations in the Rocky Mountain Region, are presented to illustrate gas-oil contacts, transition zones, oil-water contacts and coning of gas and water. Also, a comparative example of conventional (plug type) versus whole core (full diameter) analysis is presented to illustrate the importance of whole core analysis in assessing productivity of fractured reservoirs.

Introduction
Cores are taken and analyzed to permit direct examination of samples of the section so that lithologic changes can be correlated and evaluated with the subsequent core analysis data and down hole logs. Cores are analyzed to permit a direct determination of the petrophysical characteristics of the formation. These characteristics include porosity, permeability, residual fluid saturations, lithology, grain density, cation exchange capacity, electrical and elastic properties, capillarity and relative permeability. All other methods of evaluating these properties are indirect. Table No. 1 summarizes routine core analysis data and its use.

TYPES OF CORE ANALYSIS
Core analysis has evolved into two major types related to the size and portions of the core analyzed, as various formations require different analytical techniques to obtain valid data.
Fracture Characterization a Key Factor in Yates Steam Pilot Design and Implementation
Authors: Snell J. S. , Wadleigh E. E. , Tilden J. 
Published: December 2007

Abstract
The successful design and implementation of any improved oil recovery project in a fractured reservoir depends on an accurate characterization of the fracture system. This is especially true in a steam pilot project currently underway in the Yates Field of West Texas. This pilot will assess the economic viability of accelerating gravity drainage in the gas cap of the fractured San Andres reservoir. From the conceptual phase of the project through implementation and monitoring, fracture characterization in the pilot area has been critical to pilot design and success. Key decisions have depended on an accurate assessment of fracture density, orientation, flow capacity and connectivity to other portions of the reservoir. Many geologic and engineering methods have been employed to understand the fracture system. Flexure mapping, tracer testing, pressure interference testing and reservoir simulation were employed in the design phase of the project. Fluid sampling and passive microseismic monitoring have been employed to monitor the project. This paper will discuss each of these methods, field results, and key decisions that were based on the analyses.
A New Hydrodynamic Washpipe Sealing System Extends Performance Envelope and Provides Economic Benefit
Authors: Morrow W. C. , Drury R. F. , Dietle L. L. , Kalsi M. S. 
Published: December 2007

Abstract
A patented washpipe assembly has been developed that improves the economics of high speed, high pressure drilling by minimizing tripping frequency and downtime associated with conventional washpipe maintenance. The assembly addresses wear mechanisms associated with high pressure, dynamic runout, and high rotational and surface speed by employing hydrodynamic lubrication, pressure staging and component articulation. No external power sources or controls are required. This has totally changed the operational characteristics and failure dynamics of swivel sealing. This paper describes the operating principles, field performance and significant economic benefits of the new assembly.
Application of Metal-Bearing Seal Roller-Cone Bit Reduces Rig Time/Drilling Costs in Green Canyon, Deep Water Gulf of Mexico
Authors: McLeod Scott A. , O'Grady Thomas T. , Sullivan Eric C. , Mason John S. , Lin Chih 
Published: December 2007

Abstract
The application of a metal-bearing-seal roller-cone bit in Green Canyon, deep-water Gulf of Mexico has had a beneficial impact on drilling costs. Improvements in seal reliability (one million bit revs or 1000 krevs without seal failure are common) and cutting structure durability have resulted in more time "on bottom" and have permitted the operator the confidence to apply the steel-tooth roller-cone bits to directional work where polycrystalline diamond compact (PDC) bits were once required.
Typically, the operator's applications are deep and directional and water-based fluids are preferred in the upper hole section while synthetic mud is used deep in the wellbore. Periodically, the operator also uses a steerable-ream-while-drilling (SRWD) system. In all cases, the operator strives to maximize "hours on bottom".
The roller-cone bit's resistance to "balling" in water-based muds (WBM), its desirable steerability characteristics and the option to use the bit in service with the SRWD, coupled with its improved reliability, make it the appropriate tool for the application. The authors will document rig cost savings ranging from $150,000-$300,000 US in some applications.
Assurance Increased for Drill Cuttings Re-Injection in the Panuke Field Canada: Case Study of Improved Design
Authors: Guo Q. , Dutel L. J. , Wheatley G. B. , McLennan J. D. , Black A. D. 
Published: December 2007

Abstract
Disposal of oil-contaminated cuttings has become increasingly important from both economic and environmental perspectives. Re-injection through hydraulic fracturing can provide a zero discharge solution and eliminate future cleanup liabilities. The development of best practices and practical solutions for predicting fracture growth during slurry injection has accelerated the economic disposal of oily cuttings from drilling operations.
One such case is for Panuke wells, in Nova Scotia, Canada. For sections deeper than 1290 m MD, these wells are drilled with oil based mud. In the past, drilling waste was injected into an existing well, Well PI-1. A total cuttings slurry volume of 96,000 bbls had been injected through casing into well PI-1 before an additional well was planned in early 1999. Well PP3C was identified as a candidate injection well through the 11¾" × 9 " casing annulus. In order to assure the containment of fractures arising from injection, investigations were conducted on the design of the injection process using a fully three-dimensional hydraulic fracturing simulator. This paper assesses the affects of formation layering, varying permeability and elastic modulus, injection rate, and other operational procedures on the injection fracture geometry and containment.
Significant to the injection recommendations were lessons learned from a recent joint industry project on ‘drilling waste disposal’ (DEA #81). The ability to verify multiple fractures in DEA #81 from post laboratory test examination suggests that the analyses and design are adequate to assure safe containment of injected drill cuttings. The case study showed that interaction among the various factors can result in very complex fracture geometry and a true three-dimensional fracturing simulator must be used to assess fracture containment. The results provide insight into best practices for the containment of fractures, designs for successful re-injection, selection of candidate injection zones, and quality assurance.
Differentially Stuck Pipe: Early Diagnostic and Solution
Authors: Santos Helio 
Published: December 2007

Abstract
Problems with differentially stuck pipe account for huge losses in the oil industry all over the world. Being able to minimize the risk of getting stuck while drilling has been the goal recently. However, some misunderstanding and misinterpretation of current laboratory and rig tests have led operators to apply the wrong solution to the problem. This paper initially addresses how the drillstring gets differentially stuck and the main related mechanisms. The old concepts and ideas are revised here on the basis of new drilling fluids being used, especially the ones with low solids content. The simplest solution for minimizing the risk of getting stuck is described, as well as some field indications of how the problem can be detected at an earlier stage. The paper finally shows the importance of changing the way some tests are conducted today to clearly quantify the risks involved in any drilling operation.
The Mechanical Earth Model Concept and Its Application to High-Risk Well Construction Projects
Authors: Plumb Richard , Edwards Stephen , Pidcock Gary , Lee Donald , Stacey Brian 
Published: December 2007

Abstract
Many of today's well construction projects are technically and economically challenging. Examples include deepwater exploration wells in the Gulf of Mexico, offshore field development projects such as Hibernia, Newfoundland, Canada and onshore field development projects in tectonically active regions such as the Cusiana field in Colombia. Minimizing non-productive time associated with wellbore instability and unexpected pore pressure regimes reduces the risk of dangerous accidents and is required to complete the well on time and within budget. Minimizing non-productive time is a complex task that requires thorough pre-spud planning to identify drilling risks and geological hazards and to develop contingency plans for handling those risks. Building a mechanical earth model during the well planning phase and revising it in real time has proven to be extremely valuable in delivering complex wells safely while minimizing unplanned well construction costs. Monitoring and revising the model while drilling requires geomechanics expertise, teamwork, data management and excellent communications among service companies and their client.
This paper defines a mechanical earth model, explains why it is important, how it is developed and how it is applied to well construction and field development. We will discuss sources of information and the multi-disciplinary team approach required to: generate, revise and maintain an earth model. Three examples of the application of the earth model concept are discussed.
New Cement Systems for Durable Zonal Isolation
Authors: Le Roy-Delage S. , Baumgarte C. , Thiercelin M. , Vidick B. 
Published: December 2007

Abstract
In this paper we present new cement systems where the value of elastic parameters are specified to meet the requirement for long term mechanical durability. These systems can also contain expanding additives leading to an optimum configuration to prevent loss of zonal isolation due to change of downhole conditions. The advantages of these systems are demonstrated in field test cases where the cement sheath behavior as a function of changes of downhole conditions is modeled to determine whether damage could occur or not.
New Model of Pressure Reduction to Annulus During Primary Cementing
Authors: Zhou Desheng , Wojtanowicz A. K. 
Published: December 2007

Abstract
Annular pressure reduction during cementing is the major factor causing annular gas flow. It has been accepted and proven experimentally that the pressure reduction phenomenon results from the shear stress opposing downward motion of slurry undergoing to volume reduction. Mathematical models have been proposed to describe this process based on the gel strength (or shear stress) development in time. However, the models can only simulate pressure reduction process observed in the lab where compressibility of the system is very small. The models can not explain the variety of pressure reduction patterns observed in the field operations when time-dependent effects of compressibility significantly contributes to the process.
The paper presents a mathematical model combining the effects of gel strength, volume reduction, and compressibility on pressure loss in the cement column. Results from the model, shown in the paper, compared very well with the data from the laboratory and in field tests. The simulated results explained discrepancies in the pressure loss patterns observed in these tests. Main contribution of this study is to quantify the interaction between friction and de-compression mechanisms and their extend in the cement column after placement.