bluuebunny/crossref_metadata_2025_split huggingface dataset:
Applying Short-Radius Horizontal Drilling to a Deep, Hot Reservoir in the Mubarek Field
Authors: Simpson W. A. F. , Spilsbury Paul , Ali I. H. , Hargreaves Christopher 
Published: December 2007

ABSTRACT
The world's deepest short radius horizontal well was drilled by Crescent Petroleum in their offshore Mubarek Field in the second quarter of 1992. The reservoir objective was the Thamama formation which is a deep, hot, fractured limestone containing a sour gas condensate.
The well was built to horizontal at 14,115 ft TVD and over 1000 ft of the Thamama reservoir was drilled in 5-7/8" hole using short radius drilling equipment and a mixed metal hydroxide drilling fluid. The well was drilled without any major problems and a 3-1/2" perforated liner run to TD successfully.
This paper discusses the operational planning for the well including the reasons for the choice of short radius technology, the planning considerations for its application in this harsh environment and the selection of the mud system for use with the short radius motors at the high bottom hole temperature encountered in the Thamama reservoir.
A history of the overall drilling operation is discussed. The success of the short radius equipment and the mixed metal hydroxide mud system is evaluated and their performance, interaction and limitations are addressed. The problems encountered while drilling are considered and possible solutions or procedural changes which will improve performance in future wells are presented.
A Large Volume Computer System for Digitized Well Log Data
Authors: Lindseth Roy O. 
Published: December 2007

A geological well data handling system has been developed to retrieve, edit, process and display processed digitized log data in a matter of which frees the user from any routine data handling considerations. The user may collect data and submit it to the system. From that point on processing can be handled by merely processing can be handled by merely describing the location and type of data to be analyzed and the functions to be performed on the data. The system ensures the data is in the file, that it is correct, and will submit it to the requested processing procedures and display it on processing procedures and display it on some appropriate form. The system places heavy emphasis on visual places heavy emphasis on visual display. Virtually every program attempts to display the output in some form of integrated visual pattern. pattern. Digitized log data is the normal input to the system. Editing procedures examine the data for rational procedures examine the data for rational values and will indicate where data errors may exist. A preliminary analysis calculates a set of parametric statistics which aid in parametric statistics which aid in determining the quality and nature of the input data. Extensive editing is done on the data to ensure that the basic information is reliable within obtainable limits. Erroneous data is often the true culprit for many problems which at first glance appear to be hardware or software in nature.
In a typical operation some 200 wells containing roughly 1.5 million feet of digitized log are manipulated through fifty programs. Segments of the log file meeting prescribed logical conditions may be subject to analysis and the output displayed on a machine contoured map. The modular nature of the system allows successive operations to be performed in any desired order. The output of many routines is placed in a format similar to the digitized log input so that results of operations may be operated on by succeeding programs in the same manner as log data.
Use of Variable Stabilizer in Horizontal Wells
Authors: Kristiansen Egil , Jones R. D. , Eriksen T. J. 
Published: December 2007

ABSTRACT
This paper outlines the background, concept, preplanning, supervision and achievements made by use of variable gauge stabilizers in rotary drilling of horizontal wells. The experienced performance and behavior of PDM motor versus the variable gauge stabilizers are reviewed. The requirements and ability to drill at high penetration rates over long hole sections and with small vertical targets still being able to control the vertical depth within a target limit of ± 2.0 m are shown feasible. Examples from the Oseberg field will show results of the drilling operations including drilling parameters, BHA's, ROP, hole trajectory, torque and drag during the drilling and results of the consequent setting and cementation of pipe in the horizontal section.
The conclusions are; (1) rotary drilling of horizontal section gave higher ROP (m/hr), (2) inclination was satisfactory controlled with a variable gauge stabilizer over a horizontal section of 174 m, eliminating several trips and (3) this technique will enable vertical tolerances of horizontal wells as narrow as ± 1.0 m over long horizontal sections, even at high penetration rates.
Biodegradation and Drilling Fluid Chemicals
Authors: Bland R. G. , Clapper D. K. , Fleming N. M. , Hood C. A. 
Published: December 2007

ABSTRACT
Biodegradability testing of drilling fluid chemicals is becoming a requirement for use in Europe, due in part to the persistence in the environment of the oils attached to discharged cuttings from oil-based drilling fluids. This paper defines some pertinent terms, presents a brief discussion of aerobic ready biodegradability testing based on the methods published by the Organization for Economic Cooperation and Development (OECD) and presents results and experiences from using an OECD proposed seawater closed bottle test procedure to screen hydrocarbon oils and alternatives for their potential marine biodegradability.
Vertical Drilling Technology: A Milestone in Directional Drilling
Authors: Chur Claus , Oppelt Joachim 
Published: December 2007

ABSTRACT
The Continental Deep Drilling Program of the Federal Republic of Germany (KTB) is a fundamental research project to investigate the physical and chemical conditions and processes in the deep continental crust. To meet the geoscientific goals, it is necessary to drill an ultra deep borehole with a target depth of 10000 m.
To reach this depth safely it is necessary to minimize the drag and torque for the drill string as well as the loads on the casing strings. Therefore a unique drilling concept has been set up including the application of automatic Vertical Drilling Systems (VDS).
The latest development VDS-5 has an external negative steering device. Sensors, electronics, electric power supply and all hydraulic and mechanical parts are designed for an operating temperature environment up to 200°C (390°F) or a depth equivalent to 8000 m.
Applying the vertical drilling technology an average borehole inclination of less than 1° could be maintained under a foliation dip of about 60°. At a depth of 6700 m the horizontal displacement was only 4 m. Drag forces could be kept to values less than 120 kN.
Drilling results from more than 80 runs with the vertical drilling systems are reported.
These results promise various options for further development, such as an automatic closed loop drilling system for general directional drilling applications. This system could be steered either along a preprogrammed well course or with the incorporation of formation evaluation sensors, working in formation boundaries.
Surge Field Tests Highlight Dynamic Fluid Response
Authors: Wagner R. R. , Halal A. S. , Goodman M. A. 
Published: December 2007

Abstract
This paper presents actual surge and swab field data during tripping and circulating operations which include both surface and downhole measurements. These data are compared with a dynamic surge model which includes the effects of fluid inertia and compressibility, wellbore elasticity, axial elasticity of the pipe, and temperature dependent fluid properties. The transient response of measured downhole pressure, surface pump pressure, return fluid flow, and hookload are compared with the model and interpreted. The data clearly show dynamic and inertial effects not anticipated by conventional practices but predicted by the model.
Case History of Steam Injection Operations at Naval Petroleum Reserve No. 3, Teapot Dome Field, Wyoming: A Shallow Heterogeneous Light-Oil Reservoir
Authors: Olsen D. K. , Sarathi P. S. , Hendricks M. L. , Schulte R. K. , Giangiacomo L. A. 
Published: December 2007

ABSTRACT
This paper summarizes the steam injection operations of the Naval Petroleum Reserve No. 3 (NPR-3), Teapot Dome field, Wyoming, a federally owned oilfield, located about 35 miles north of Casper, Wyoming. More than 24 million barrels of oil has been produced since initiation of production in 1922; more than 15 million barrels has been produced since full production began in 1976. The Shannon sandstone is the shallowest (350 to 500 ft) and most productive of nine producing zones and accounts for 55% of current production. The Shannon, composed of the Upper and Lower Shannon sandstones, was deposited as an offshore bar where bar margin, inter bar and bioturbated shelf sandstones are the reservoir. The reservoir is faulted and extensively fractured, with the two sandstone intervals separated by shaly non-productive siltstone. Maximum gross sand thickness is 100 ft with an average porosity of 18% and 63 mD air permeability.
Since only 5% of the Shannon's 144 million barrels of original oil-in-place was estimated to be recoverable by primary means, a study of recovery technologies was conducted in 1980 resulting in implementation of a polymer-improved waterflood pilot and an in situ combustion pilot in 1981. The polymer pilot was unsuccessful, while the in situ combustion pilot was considered a technical success although marginally economic. Favorable response to steam preheating in the in situ combustion pilot led to the development of a steamdrive pilot in October 1985. Favorable response in the steamflood pilot led to recent rapid expansion. Currently 150 acres are being flooded using five 50MMBtu/hr steam generators. The history of the steamflood has been reviewed in an effort to document successful application of steamflooding in a shallow, very heterogeneous, low-permeability, light oil (32° API gravity) reservoir which defies conventional screening criteria.
Evaluation of a New Method for Steamflooding Multisand Reservoirs
Authors: Kumar Mridul 
Published: December 2007

ABSTRACT
A novel method of simultaneously processing two sands using a single injection string (the "checkerboard" injection scheme), in which adjacent pattern injectors are completed alternately into upper and lower sands, is evaluated numerically. The new scheme is compared with two others: (1) the conventional "sequential" injection and (2) the case where steam is injected into the lower sand only and the "hot-plate"-heated upper sand is drained by gravity alone.
Results show that the checkerboard injection scheme is superior to the sequential for a constant oil and gas price scenario. It results in accelerated production and has lower completion costs. However, the sequential scheme results in the highest recovery. The checkerboard scheme may be especially useful in situations where acceleration of oil recovery may be desired or when the steam injection period may be limited by external constraints. Oil production from the heated upper sand by gravity drainage alone results in the lowest recovery and is not recommended (unless steam injection in the upper sand is uneconomic). Results also show that, for this nondipping reservoir, a significant amount oil is recovered from heated areas outside the pattern boundaries.
Comparison of Thermal EOR Processes Using Combinations of Vertical and Horizontal Wells
Authors: Sarkar Avik , Deo M. D. 
Published: December 2007

ABSTRACT
A comparison of three thermal EOR processes; SAGD (Steam Assisted Gravity Drainage), HASD (Heated Annulus Steam Drive) and CYS (Cyclic Steam Stimulation), has been made using a three dimensional thermal simulator by employing a combination of vertical and horizontal wells. Reservoir characteristics and thermal and fluid properties were maintained identical for process comparison. A 10-year project-time study was undertaken for CYS with vertical wells, CYS with horizontal wells, HASD with horizontal HAS pipe and aligned vertical injector and producer, HASD with offset vertical producers, and SAGD with horizontal injector and producer. The effect of reservoir heterogeneities on process performance was also examined. CYS vertical performed significantly better than CYS horizontal both in terms of cumulative % OOIP recovery and SOR. HASD recovered more oil, though the initial production rate in HASD was low. SOR in HASD was, however, very unfavorable (more than twice that of CYS vertical). HASD with offset wells made both SOR and % OOIP recovery more favorable. SAGD had better SOR than HASD; however, it recovered about half the oil recovered by HASD at the end of ten years. An unfavorable heterogeneity feature (low permeability layers or barriers) affected the recoveries and SORs for the horizontal well processes more adversely than vertical well processes.
Conformance Evolution during Cyclic Steam Stimulation in Cold Lake Reservoir
Authors: Wu Ray S. , Kry P. R. 
Published: December 2007

Abstract
Two observation wells, both instrumented with casing external thermocouples and one instrumented with casing external pressure transducers, were located 11 m and 25 m from a Cyclic Steam Stimulation well. The closer well was installed after 2 cycles of Cyclic Steam Stimulation and showed that the areal heated zone conformance changed little over the next several cycles. Most of the production was supported by increases in vertical conformance. The second well was installed after 5 cycles of Cyclic Steam Stimulation and demonstrated that non condensible gas saturation in later cycles controls the distribution of steam before the highest injection pressures are reached.
Development and Application of Pseudo-Functions for Reservoir Simulation To Represent Shear Failure During the Cyclic Steam Process
Authors: Ito Yoshiaki , Settari Antonin , Kry P. R. , Jha K. N. 
Published: December 2007

ABSTRACT
The steam stimulation process is a proven, commercially viable recovery process in oil sand reservoirs. However, uncertainties remain in the analysis of the recovery mechanism of the process. One of the important aspects is the nature of shear failure created by pore pressure increase in the reservoir during steam injection. The changes in mass and heat transport properties in the heterogeneously deformed failure zone have been shown to be major factors affecting the recovery mechanism. This paper describes the theoretical and practical aspects of representing the shear failure sone in reservoir simulation, by means of pseudo relative permeability functions.
Relative permeability hysteresis is commonly used in the simulation of the steam stimulation process. The paper gives the theory for the pseudo relative permeabilities caused by heterogeneously failed media. The new functions are derived by considering the shear failure phenomenon and have a characteristic similar to relative permeability hysteresis. A set of stress-dependent pseudo relative permeabilities is proposed and a practical method for the use of the pseudo functions (including hysteresis) in a reservoir simulator is given. The pseudo relative permeability model is applied in the simulation of a well in the Esso Cold Lake site and shows that the hysteresis should be stress-dependent rather than saturation-dependent.
Stability of Conventional and Ceramic Gravel Park in Well Associated to an EOR
Authors: Alcocer C. F. , Toups M. , Hayatdavoudi A. , Okoye C. U. , Ghalambor Ali 
Published: December 2007

ABSTRACT
The main objective of this research was to determine the effects of elevated temperatures on the size and shape of gravel pack materials, specifically as related to the generation of fines within the gravel pack itself. These objectives were achieved by examining 20/40 and 40/60 mesh samples of subject materials for the influence of various temperatures (room temperature up to 500°F). SEM photographs of 40/60 mesh gravel indicated an increased amount of pits caused by temperature. Also, the formation of striations and/or flaking were present on the 40/60 mesh gravel.
Stress Changes in Thermal Operations
Authors: Dusseault M. B. 
Published: December 2007

Abstract
Large-scale fracturing, fire floods, or hot water injection can alter principal stress magnitudes (σ1,σ2,σ3) and directions, even at the reservoir scale. In fracturing, this leads to changes in fracture orientation (Dusseault and Simmons, 1982); in firefloods, stress changes lead to yield and microseismic emissions, impairment of reservoir seal, and well loss through shear (Dusseault et al., 1988); hot or cold water injection can induce shear failure or tensile stress zones around the injection borehole (Hojka et al., 1993). Pore pressure changes also alter total and effective stresses (σ, σ’), and sand production or sand injection will lead to reservoir-scale stress changes (Dusseault and Santarelli, 1989).
This article addresses stress changes during thermal operations. Thermal loading is often a non-linear problem because reservoir response is modified:
principal stress fields are rotated and altered; volume changes occur and stresses change; yield and dilation of the reservoir occurs; absolute and relative permeability changes because of dilation and saturation alteration; bounding strata properties may be affected by tensile cracking or shear yield; and, overburden or reservoir shearing develops because of high pore pressures, thermal stresses, and weakening due to yield.
Surface Control on Thermal Front Movement in Fireflooding Process
Authors: Diyashev R. N. , Galeev R. G. , Kondrashkin V. F. , Shvydkin E. K. 
Published: December 2007

ABSTRACT
This paper presents some data about heavy oil and bitumen reservoirs in Tatarstan (Russia), methods and results of surface magnetic and electric survey with the purpose of determination the burned and heated zones of formation as well as in-situ combustion front movement. Information receiving helps to increase sweep efficiency during the process.
Computed Relative Permeability Drainage and Imbibition
Authors: Ashford Frank E. 
Published: December 2007

Abstract
A brief review of the historical developments of both drainage and imbibition relative permeability reveals shortcomings in previously permeability reveals shortcomings in previously applied mathematical models.
Recent investigations indicate justifiable bases for relating the Leverett "J" function directly to the relative permeabilities of both phases. Development of this procedure yields a phases. Development of this procedure yields a relationship describing the "J" function in terms of rock matrix properties, i.e.: k, krw, phi, Sw, the absolute permeability, the wetting phase relative permeability, the porosity, and wetting phase saturation, respectively.
(Equations) are the expressions for the drainage cycle, while
(Equations) are the expressions for the imbibition cycle.
The saturation exponent relates the relative permeabilities to pertinent matrix parameters. The result is considered an improvement parameters. The result is considered an improvement over previous models that assumed krw and krnw to be exclusive functions of the mobile wetting phase saturation. A method is also presented for phase saturation. A method is also presented for computing a pseudo irreducible water saturation, Swp, below which krw is assumed negligible. The application of this value to relative permeability calculations has been very successful.
Recent imbibition relative permeability studies have yielded a model that predicts imbibition parameters from drainage values. The model is an extension of the Naar-Henderson treatment.
Option Theory for Evaluation of Oil and Gas Assets: The Upsides and Downsides
Authors: Lohrenz John , Dickens R. N. 
Published: December 2007

ABSTRACT
Assumptions encumbering option theory methods for valuation of oil and gas assets, unlike purely financial assets, are reviewed and shown to severely burden getting serviceable answers. In fact as a general rule, the further upstream the oil and gas asset valuated with option theory methods is, the more so the assumptions may be called into question.
A Comprehensive Model of Minifrac Pressure Behavior With Foam Fracturing Fluids
Authors: Zhu Ding , Hill A. D. 
Published: December 2007

ABSTRACT
A comprehensive model of pressure behavior in a minifrac test with a compressible fluid (a fluid for which the density is a function of temperature and pressure) has been developed to simulate the pressure behavior more accurately and realistically. Since for minifrac tests, the fracture will more likely be radially expanding, Geertsma's penny-shaped fracture geometry model has been introduced to modify an existing linear fracture model. The new model handles a wide range of frac fluids using the proper equations of state to simulate slightly compressible fluids or highly compressible fluids such as high quality foams. In the case of surface shut-in, the effect of wellbore fluid warming due to the geothermal heating along the wellbore on the pressure decline is also examined.
Numerical solution of the model shows that the pressure decline after shut-in will be affected by the frac-fluid warming if the fluid is compressible. The higher the gas quality of a foam is, the more pronounced this effect will be. The leakoff coefficient evaluated frompressure decline using the Nolte model will be in error at early shut-in time. The wellbore fluid warming adds more inaccuracy to the leakoff estimation. The estimate error caused by the fluid warming in the fracture will decrease to zero as the fracture closure time fracture approaches.