bluuebunny/crossref_metadata_2025_split huggingface dataset:
Water Control for Enhanced Oil Recovery
Authors: Cole R. Clay , Mody Bharat , Pace Jim 
Published: December 2007

Abstract
Gains in recovery efficiency in West Texas oil and gas fields have been realized as a result of applying four different chemical processes, either singly or in combination. Each of the four chemical processes reviewed has been tailored to meet certain specific reservoir requirements. For example, complete plugging of high flow capacity channels can often be accomplished. If desired, the high water production portion of a producing zone can be sealed by injection of gel-forming chemicals into the matrix. Both floodwater diversion and water-oil mobility ratio improvement can be attained by in situ polymerization of a unique one-stage polymer bank in the reservoir. In producing wells, the water-oil production ratio often can be favourably changed by treating certain formulations with a nonplugging polymer which tends to restrict water flow but not oil.
One feature which each of the four processes has in common is the ability to invade deeply into matrix which may produce long lasting results.
A description of each process is presented along with various placement techniques which have been used to obtain optimum results. Data from fields which have benefited from these treatments are presented. The paper describes what may be expected with each of these proven processes based on field results.
New Teshniques of Pipeline Inspection
Authors: Herve J. L. , Ling M. T. S. , Undeli J. 
Published: December 2007

Abstract
The Frigg Field Transportation System was commissioned in 1977. Since starting production, Total Oil Marine has initiated and maintained an in service inspection programme designed to identify any condition of the line which may lead to failure of the line either in the short or long term. Until 1980, the main problems on the pipeline were identified as short term stability problems. We believe that our current inspection programme is adequate to identify rapidly any area of concern. In 1981 our main effort is to determine the best methods for identifying longer term problems such as internal and external corrosion. Our current programme therefore now has three main aspects. The external inspection, performed routinely over the past four years, cathodic protection inspection tested in 1980, and an internal pigging programme which was initiated in 1978.
The full inspection programme will be the subject of this paper.
"Offshore Cranes" - A Case History
Authors: Barber J. C. , Wheeler M. , Adams A. 
Published: December 2007

Abstract
Prior to July 1978 several pedestal crane accidents occurred which resulted in considerable investigation by the Department of Energy. The outcome of the investigation resulted in legislative changes in crane operation, the most stringent being the requirement for inspection of the slewing ring bearings within a fixed period of time and thereafter at three yearly intervals.
Total Oil Marine (TOM), as a result of this legislation, commenced various studies to investigate the safest and most economical methods of completing the required inspection.
These studies confirmed that for TOM the best method would be to lift the cranes from the pedestals to provide maximum flexibility for undertaking all work envisaged. The lifting would be done, using a derrick crane for which the primary installation already existed on the north deck of the platform (MCP-01).
Waterflooding of Channel Sandstone Reservoirs
Authors: Yinan Qiu , Ziqi Chen , Shice Xu 
Published: December 2007

ABSTRACT
Channel sandstones occupy a particularly important place among the sandstone reservoirs deposited in lake basin. According to statistics of fourteen main oilfields in China, the oil reserves in channel sandstones are more than half of total ones. Within a depositional system the channel sand stones are always deposited in a intermediate position and they have moderate grain size and sorting to become main reservoirs with highest permeability. The inner sequence of grain size of channel sandbodies is characterized by normal rhythm, which leads to serious in-layer heterogeneity, less conformance factor in thickness and rapid rising of water cut. Channel sandbodies exhibit significant directional permeability. Injected water rapidly tongue along the ancient channels and preferentially flow toward the down stream direction. Various channel sandstones are different in-layer heterogeneity, and so in production performance.
Application of Water-Base Mud in Deep Well Drilling
Authors: Yingan Li , Fayuan Qian , Pingya Lo 
Published: December 2007

ABSTRACT
This paper deals with the major problems in the application of high-temperature resistant muds for deep well drilling, based on laboratory research and the practice in the drilling operation of 6000-7000m wells in Sichuan Province, China. Major problems, such as the stability of the mud, property adjustment and control of the mud under high temperature and pressure, and effect of PH on the properties of the mud system etc., and the way to solve these problems. Prevention of drill pipe stuck in deep well drilling using weighted mud, and prevention of H2S contamination on the mud system are also discussed. Mechanism of high-temperature effects on mud system are investigated preliminary. Laboratory work and field practice about the application of SMC, SWT and SMP to establish high-temperature and high salt content water base mud systems are presented.
Casson Rheological Model In Drilling Fluid Mechanics
Authors: Wang Zhongying , Tang Songran 
Published: December 2007

Abstract
The Casson rheological model gives a better description of the rheological characteristics of drilling fluids than the Bingham and power law models. In this paper, a method for experimental verification is given, relevant test results are reported, flow profiles in pipe and annulus are analysed and several rheological formula concerning pressure drop, thinning index are derived.

Introduction
Drilling muds are fluids with complicated constitutions. Both the Bingham and power law models have been widely used in the research for the description of the shear stress vs. shear rate relationship in drilling fluids. As it is well known, the Bingham model is good enough in medium and high rate ranges.
Gravel Transport in Deviated Wellbores
Authors: Hodge Richard M. 
Published: December 2007

Abstract
A computer program has been developed to predict gravel placement effectiveness for a specific gravel-pack design. This program was developed as the direct result of recent studies using a large-scale, transparent, deviated wellbore model.
Earlier studies have addressed the problems associated with gravel packing deviated wellbores. Each of these studies has utilized wellbore models and circulatory techniques to illustrate the placement of gravel packs. Each also proposed various solutions to maximize the packing efficiency. A mathematical model was reported in these earlier studies which related wellbore condition and fluid properties to gravel placement effectiveness for a specific gravel-pack design. This most recent work was conducted in order to determine the accuracy of that math model prediction.
The accuracy of the computer predictions was evaluated by the use of a series of test gravel packs performed with the wellbore model. Throughout the testing, fluid density, fluid viscosity, particle size, particle density and concentration, percentage of flow loss, and casing I.D. were held constant. The pump rate, screen and tailpipe size, and angle of deviation were varied.
In each test predicted to produce a complete pack, 95 to 100% of the casing volume throughout the length of the screen was packed properly.
Effect of Flow Rate and Rheology on Shear Strength of Migrating Formation Fines Due to Flow of Pseudoplastic Fluids
Authors: SenGupta Sujit Kumar , Hayatdavoudi A. , Tiab J. O. , Kalra Satish Kumar , LeBlanc James L. , Schluntz E. K. 
Published: December 2007

ABSTRACT
Recent investigations have established the fact that authigenic clays may be dislodged during the enhanced oil recovery operations. However no mechanical stabilization of these clays along with chemical treatments has been fully used or investigated. The mechanical unstability of the clays is due to stress variation at the pore surfaces of the reservoir rock during the flow of pseudoplastic fluid such as polymer, etc. An equation has been derived which shows the relationship between the stress developed and the radial distance from the well bore at constant injection pressure.
The analysis of this equation shows that the stress is maximum near the well bore and decreases rapidly with distance. Graphs have been plotted to show further the effect of flow rate and power law coefficient on the stress.
Laboratory Evaluation of Sodium Hydroxide and Sodium Orthosilicate for Tertiary Oil Recovery in an Alberta Reservoir
Authors: Novosad Zdenka , McCaffery Frank G. 
Published: December 2007

ABSTRACT
Laboratory evaluations of sodium hydroxide and sodium orthosilicate as improved oil recovery agents have been made for the Wainwright reservoir of Alberta. This reservoir contains acidic oil and has undergone extensive waterflooding. Both the in-place brine and the brine presently being injected into the Wainwright reservoir are very hard, suggesting that the injection of the two alkaline agents as slugs in the tertiary mode might result in different oil recoveries.
Preliminary phases of the study involved evaluation of interfacial tension (IFT) between Wainwright oil and solutions of both alkaline agents at various concentration levels as a function of salinity and hardness. Included were tests of chemical reactivity of hard Wainwright waters with the two alkaline agents. With soft Water, the measured IFT values for crude oil/alkaline solutions did not vary widely, and were generally less than or equal to 0.5 mN/m. Tests with hard water confirmed the superior ability of sodium orthosilicate to remove free hardness ions from solution.
The relative oil recovery efficiencies of 50% PV slugs of the two alkaline agents at a 1.0 wt% concentration were studied in six Berea core displacement tests. The effects of the addition of salt to the slugs and of applying soft water pre- and post-flushes were also evaluated. Sodium orthosilicate performed better than NaOH in the core subjected to soft water pre- and post-flushes when no NaCl was added to the alkaline slug. The improvement in oil recovery over waterflooding amounted to 15% OOIP. Oil recoveries were very similar for both agents when no soft water preflush was conducted, or when 1% NaCl was added to the alkaline and preflush slugs. Chemical losses evaluated in the core floods were found to be similar for both agents. The oil recovery and pressure drop data are reviewed and discussed in terms of the alkaline flooding mechanisms that appear to prevail.
California Offshore Platform Development
Authors: Visser Robert C. 
Published: December 2007

ABSTRACT
This paper presents a historical overview of platform design and construction offshore California. Twenty-two platforms and seven islands have been installed since the first island was installed offshore Seal Beach in 1948. Seismic design requirements, steeply sloping ocean bottoms, limited availability of heavy derrick barge equipment and unusual producing requirements resulted in a number of innovative platform designs.
The first platform was installed offshore California in 1958. This structure, platform Hazel, was also the world's first gravity platform. Platform Hilda was the first tilt-up structure. Platform Hondo, in 850 feet of water, was fabricated in two sections and these were joined underwater after they were launched. Platform Emmy is one of the few platforms that were equipped with pumping units for artificial lift. The paper describes the design considerations involved with these platforms as well as the fabrication and installation methods employed.
Obtaining Quality Primary Cement Jobs in the Williston Basin
Authors: Ford Randle E. , Turcich Thomas A. , Pierson Ronald A. , Ramsey Leland K. , Divan Daniel J. 
Published: December 2007

ABSTRACT
A compilation of literature dealing with drilling and completing through salt formations is examined and summarized. This literature is adapted to the special conditions present in the Williston Basin, especially in the Madison Group.
Discussion includes drilling in-gauge hole through the Charles and the Spearfish and getting adequate mud removal throughout the hole. Mechanical means of insuring cement bond to the pipe and to the formation are discussed as is the failure mode of cement in salt. A cement and casing design is proposed which keep the hydrostatic head on the Mission Canyon within tolerable limits while still providing for a strong cement.
The suggestion is made that a major contributor to early casing failure in salt formations is pipe set in compression loading. This hypothesis is discussed at length. A method for ensuring tension loading through the Charles and Spearfish is presented.
Transient Pressure Analysis of Hydraulically Fractured Wells in the Western Tight Sands
Authors: Ahmed Usman 
Published: December 2007

ABSTRACT
Currently there are five basic techniques which can be used to analyze transient pressure data from hydraulically fractured wells. They are: modified pseudo-radial flow (semi-log analysis), formation linear flow (square-root time analysis), bilinear flow (fourth-root time analysis), type curve analysis, and reservoir simulation history matching analysis. These techniques are applied to evaluate the following parameters: formation matrix permeability, created fracture half length and fracture conductivity. Each technique has its advantages and disadvantages in estimating the above-mentioned parameters. Examples of transient pressure analysis for hydraulically fractured wells in the Western Tight Sands area have been used to demonstrate how the different techniques can provide a range of values for the above parameters. Specific techniques, however, can provide accurate results of some parameters. A representative example shows the matrix permeability calculations to range between 0.02 and 0.051 rnd as compared to the design parameter of 0.025 md. The fracture half length and conductivity estimates varied between 242-1425 ft and 56-253 md-ft compared to the design parameter of 500 ft and 200 md-ft, respectively.
Higher Sand Concentrations in East Texas
Authors: Watkins Hunter 
Published: December 2007

ABSTRACT
As more gas wells have been completed in East Texas on 160 acre spacing, fracturing down casing has become more prevalent as the best way to stimulate these wells. Field trends have been toward higher sand concentrations. Most wells were fractured earlier through 2 7/8″ tubing with maximum concentrations of 3 lbs./gal. 20-40 Mesh Sand. However, as wells were produced, it became evident that longer fractures and higher flow capacities were needed. The casing fracturing technique permitted higher pumping rates which allowed higher sand concentrations to be placed. These began to be placed at 4 lbs. and 5 lbs./gal. and have now successfully been placed at concentrations in the 7 lbs. to 10 lbs./gal. range. Recently several jobs have been placed at 15 lbs./gal.
These higher sand concentrations as compared to a lower sand concentration in an equal predicted propped fracture length seem to be giving improved clean-up of fracture fluids and longer stabilized flow rates. This improved clean-up is probably due to the higher fracture flow capacity to a multi-phase fluid which is present in the fractures immediately after fracturing. The higher fracture flow capacity also would be maintained even with fines and residue from treatment fluids thus yielding the better stabilized flow rates.
Measurement of Salinity Effects on Tight Gas Sands With a Computer Controlled Permeameter
Authors: Walls Joel D. 
Published: December 2007

ABSTRACT
A completely computer controlled pulse-decay permeameter has been designed and constructed. This system can rapidly and accurately measure gas permeability on five samples simultaneously. The samples can be partially saturated with brine or oil and can be placed under confining pressure up to 100 MPa (15,000 psi) and pore pressure to 70 MPa (10,000 psi). The range of permeabilities measurable is 10−8 μm2 (0.00001 md) to 10−3 μm2 (1 md).
To determine the effect of different brine mixtures on tight gas sand permeability, we saturated five adjacently cut Spirit River sandstones with five different fluids; distilled water, 5 NaCl, 10% NaCl, 1% KC1 and 5% KC1. The samples were dried to 66% saturation and gas permeability was measured under in situ pore pressure and confining pressure. This process was repeated, with appropriate equilibration time, for 55, 44, 33 and 22% saturation. The gas permeability vs. saturation curves are very similar, indicating that the samples are not sensitive to the type of fluid in the pores. This can be important in selecting fluid compositions for fracturing procedures. Scanning electron microscope photos of the samples made before and after saturation show no change in the structure of the clays which were primarily chlorite and illite.
Secondary Gas Recovery From a Watered-Out Reservoir
Authors: Boyd W. E. , Christian L. D. , Danielsen C. L. 
Published: December 2007

ABSTRACT
A field test of the depressuring process used to remobilize and produce trapped gas from a watered-out reservoir is described. Actual performance is compared with predictions at two different points in time showing the modifications to the reservoir-aquifer simulation model that were required to obtain pressure matches. Increased water production rates, justified by the improved simulation model, led to the production of secondary recovery gas and, in turn, to the conclusion that the depressuring process is working.
The Department of Energy's Western Gas Sands Project Multi-Well Experiment Update
Authors: Crawley Alex B. , Northrop Dave A. , Sattler Allan R. 
Published: December 2007

ABSTRACT
The Department of Energy has initiated a Multi-well Experiment with the objectives: (1) characterization of low permeability, lenticular gas sands and (2) evaluation of state-of-the-art and developing technology for their production. The location is in the Rulison Field in the Piceance Basin, Garfield County, Colorado where the lenticular Mesaverde sequence and the underlying blanket Corcoran-Cozzette are the formations of interest and lie at depths between 4,000 and 8,600 ft.
Features of this research-oriented field experiment include: (1) three close-spaced wells (100 to 500 ft) for reservoir characterization, conventional well tests, interference testing, well-to-well geophysical profiling, and placement of diagnostic instrumentation adjacent to fracture treatments; (2) complete core taken through the formations of interest; (3) a comprehensive core analysis program; (4) an extensive logging program featuring conventional and experimental logs; (5) determination of in situ stress in sand lenses and bounding shales; (6) application of geophysical techniques to determine sand lens orientation; (7) use of seismic, electrical potential and tilt diagnostic methods for hydraulic fracture characterization; and (8) a series of stimulation experiments.
Analysis of data from these activities will yield the following kinds of information: (1) geologic characterization emphasizing the morphology, properites and variability of lenticular sands; (2) a reservoir model for lenticular sand production; (3) a fracture model including correlations between stress, geometry and lens orientation; (4) core-log-well test correlations for improved formation evaluation, and (5) economic assessments.
This paper is a survey of the findings to date. It includes a discussion of a study of the most relative outcrops; the drilling program; core analysis; and well-to-well correlation of the geology.
Two wells have been drilled, the first was continously cored through the Mesaverde section from 4,310 to 6,820 ft. In the second well, 950 ft of core was taken, which include all the zones of interest for stimulation experiments.
Significant overpressuring was encountered and a large number of fractures were observed in the core, some open up to 3/4-inch width with partial mineralization. Preliminary indications are that natural fractures may play a much larger role in gas production from the low permeability lenticular sand than had previously been thought.
A Comparative Analysis of Drilling Results Obtained with Oil Mud vs. Water-Base Mud at High Island Block A-270
Authors: Nance W. B. , Muncy D. D. , Garrett M. M. , Gault A. D. , Kortlang W. F. 
Published: December 2007

Abstract
Three wells on the High Island A-270B platform were drilled with water base muds and three were drilled with inverted emulsion oil muds. The drilling performance of these two mud types was compared for the six wells.
Overall drilling costs were significantly lower with the oil muds due to the elimination of differential pressure pipe and casing sticking.
Storage of Drilling Machinery
Authors: Makins J. E. 
Published: December 2007

ABSTRACT
Storage of drilling machinery has typically consisted of simply "stacking" the rig in a yard until the next contract is obtained. In some cases a fresh coat of paint may have been applied to give the equipment some protection. To minimize machinery deterioration and subsequent start-up problems, more extensive protection is required particularly for extended storage periods. Suggested storage procedures for rig components are presented in this paper.
Techniques for Handling Upward Migration of Gas Kicks in a Shut-In Well
Authors: Mathews J. L. , Bourgoyne A. T. 
Published: December 2007

ABSTRACT
This paper discusses the experimental evaluation of various proposed well control techniques which may be implemented when normal kill operations are delayed. Two 6000-ft wells, one containing the flow geometry present in a surface blowout preventer (BOP) stack and the other modeling the flow geometry of a subsea BOP stack in 3000 ft. of water, were used to evaluate (1) the constant drill pipe pressure method and (2) the static and dynamic volumetric methods that can be employed when a meaningful drill pipe pressure is not available. It was found that any of the three methods could be used to maintain an acceptable bottom hole pressure in a surface BOP system with a uniform annular geometry. However, the static volumetric method generally resulted in a decreasing bottom hole pressure once gas reaches the subsea choke line and is not recommended for deep-water floating drilling operations.