bluuebunny/crossref_metadata_2025_split huggingface dataset:
Critical Design Parameters to Prevent Gas Invasion During Cementing Operations
Authors: Bannister C. E. , Shuster G. E. , Wooldridge L. A. , Jones M. J. , Birch A. G. 
Published: December 2007

ABSTRACT
Subterranean hydrocarbon deposits often contain low-molecular-weight gaseous hydrocarbons at various pressures, temperatures and depths. Failure to prevent the invasion of this gas into a cement slurry during completion can result in numerous problems. A few of the known manifestations of gas channeling are poor zonal isolation, annular pressure buildup, loss of hydrocarbons to nonrecoverable zones, required squeeze cementing and flow of gas to the surface.
The invasion of gas into cement slurries has been studied using a simulated wellbore model. Results indicate that a cement slurry loses its ability to transmit pressure with time. This loss is caused by gel structure development due, in part, to cement hydration and fluid loss. Gas flow can be initiated when the pressure transmitted by the fluid column becomes less than the gas pressure. The relationship between gas flow and this pressure differential has been determined for several cement systems. This relationship has been termed "gas conductivity" and is a measure of gas permeability of cement slurries prior to the development of compressive strength.
Two different design approaches were investigated in order to reduce gas conductivities in cement slurries. One involves inhibition of gas flow by the deposition of an impermeable cement filter cake against the formation. The second design incorporates a modified cement slurry which interacts with incoming gas to form an impermeable barrier in the cement pore spaces, thereby inhibiting further gas flow. The use of this "gas-induced" cement barrier to prevent gas flow has been successfully applied in Canada, Europe and the United States. Several case histories are discussed.
Field Evaluation of an Impermeable Cement System for Controlling Gas Migration
Authors: Cheung P. R. , Myrick B. D. 
Published: December 2007

ABSTRACT
The petroleum industry has recognized the problem of gas flow after cementing for more than two decades. Several laboratory investigations and field studies have been conducted in an attempt to solve the gas migration problem. However, most of the previous field practices designed to control the gas migration problem have been either unsuccessful or only partially successful.
A study of the cause and a laboratory-developed solution for controlling the gas migration problem were presented in SPE 11207. The present paper summarizes the field results obtained during an eighteen-month period using an "impermeable cement" system to control the gas migration problem. Results of 84 cement jobs performed in Texas, Oklahoma, New Mexico and Louisiana are summarized, and unique field cases are discussed in detail. All four major types of cementing jobs have been performed using the "impermeable cement" system and an overall success ratio of over 90% was obtained.
Resin-Coated Sand Slurry Pack Gas Deliverabilities: Field and Laboratory Results
Authors: Nelson Chris , Wilson Bill , Stadleman Jeff 
Published: December 2007

ABSTRACT
Although through-tubing resin-coated sand slurry packs (RCSSP's) are significantly less expensive than conventional gravel packs, they have not been widely used as a sand control completion technique. This low usage is mainly due to two inherent problems. The first is the high risk of localized pack failure in the perforation tunnels when the RCSSP casing plug is milled out. The second problem is the difficulty associated with predicting flow rates (and therefore economics) of RCSSP completed wells, especially if the casing plug is not milled out.
This paper presents a modified velocity coefficient correlation for gas turbulence, an innovative RCSSP completion configuration with an associated simulation technique, and supporting field results that demonstrate an expanded application for RCSSP's in the area of gas well through-tubing plugbacks where, until recently, their general application was thought to be uneconomical.
Single-Well Evaluation Program for Micellar/Polymer Recovery, Main and 99 West Pools, West Coyote Field, California
Authors: Holland K. M. , Porter L. T. 
Published: December 2007

ABSTRACT
The Main and 99 West Pools of the West Coyote Field were selected as promising candidates for a micellar-polymer recovery project. Waterfloods initiated in 1961 are nearing their economic limit, with a current water-oil ratio of 45. Well MC 374 was drilled in a watered-out portion of the Main and 99 West reservoirs to accomplish an evaluation program with the following objectives: Provide data for an improved geological model.Estimate current oil in place.Determine the effectiveness of micellar-polymer chemicals in displacing residual oil.
MC 374 was extensively cored and logged to provide the necessary geological and reservoir data. A multi-well interference test was conducted to confirm reservoir continuity near the test well. Displacement tests were run in two intervals with micellar-polymer chemicals. Oil saturations in the near-wellbore area were measured before and after the displacement tests using log-inject-log and single-well-tracer techniques. An extended polymer injectivity test was conducted in one of the intervals.
This paper summarizes the various phases of the overall program, from chemical selection to field operations. Primary emphasis is on the various techniques used for measuring fluid saturations and the result of those measurements.
The Single Steel Drilling Caisson: A Novel Approach to Bottom-Founded Structures in Arctic Waters
Authors: Fitzpatrick John 
Published: December 2007

ABSTRACT
In 1982, a mobile, bottom founded steel caisson drilling system, was conceived, constructed and installed on an underwater sand berm in 31 m of water, in the active shear zone of the Canadian Beaufort Sea. Discussed below are the principal design criteria, the ice/structure/foundation interaction, the construction and installation, and the post set down stress analysis of the steel caisson.
Comprehensive Geological and Reservoir Engineering Evaluation of the Lower San Andres Dolomite Reservoir, Mallet Lease, Slaughter Field, Hockley County, Texas
Authors: Behm E. J. , Ebanks W. J. 
Published: December 2007

ABSTRACT
The Mallet Lease, Hockley County, western Texas, produces oil from the Permian San Andres Dolomite as part of the larger Slaughter Field. The Mallet Lease is being considered for infill drilling and for tertiary recovery. This paper discusses the engineering and geologic basis of the reservoir description that is used in history matching 40 years of primary and secondary performance. Emphasis is given to integration of reservoir description with necessary fluid flow properties needed to match performance and also the use of long term data to insure proper reservoir representation.
There are no discontinuous, isolated portions of the reservoir that would be tapped by infill wells. Most of the remaining oil is located in the tighter portions of the producing intervals which bears on prospects for infill drilling and tertiary oil recovery.
Bonus Bidding and Bottom Lines: Federal Offshore Oil and Gas
Authors: Lohrenz John , Dougherty E. L. 
Published: December 2007

ABSTRACT
Much can be observed in the statistics of bonus bids. For one thing, more information about a lease may not mean bidders agree more with their bids. However, whether any or all bidders are achieving satisfactory results at their bottom lines cannot be observed from bid statistics. Indeed, it does appear that bidders' results are not satisfactory. Furthermore, an aggressive bidder who "wins" at bidding time appears, in this study, less profitable than a conservative bodder.
Binary Surfactant Mixtures for Minimizing Alcohol Cosolvent Requirements
Authors: Lelanne-Cassou C. , Carmona I. , Fortney L. , Samii A. , Schechter R. S. , Wade W. H. , Weerasooriya V. , Yiv S. 
Published: December 2007

ABSTRACT
The role of alcohols in microemulsion formation is two-fold. They are used to bring the oil/water/surfactant system to its optimum formulation and they destroy highly extended structures, generating instead microemulsion. Given the freedom of choice among surfactants and their mixtures, the former role of the alcohol can easily be obviated. However, the latter requirement is more fundamental and not so easily removed. This study provides guidance in the purposeful construction of mixtures of synthetic surfactants which can minimize or eliminate alcohol requirements, depending on temperature and salinity. The approach was to mix straight tailed (high solubilization) species with mid-chain branched (low cosolvent requirement) species in a spectrum of mole ratios and reduce the alcohol concentration to the point that phase transitions destroyed the microemulsion. A number of systems were identified with acceptably large solubilization parameters and no residual cosolvent requirements.
A Study for Development of a Plan of Depletion in a Rich Gas Condensate Reservoir: Anschutz Ranch East Unit, Summit County, Utah, Uinta County, Wyoming
Authors: Kleinsteiber S. W. , Wendschlag D. D. , Calvin J. W. 
Published: December 2007

ABSTRACT
The Anschutz Ranch East field is the largest hydrocarbon accumulation discovered to date in the Western Overthrust Belt. Analyses of reservoir fluid samples from the discovery well indicated that the fluid is a rich gas condensate with liquid dropout under reservoir conditions as high as 40 percent of the hydrocarbon pore volume. The proximity of the fluid dew point pressure to the original reservoir pressure dictated that a plan-of-depletion be established very early in the life of the field to avoid reservoir damage and the potential loss of significant liquid reserves. This requirement was further amplified by the fact that some of the depletion alternatives involved major front-end monetary commitments and long lead times for implementation.
Using preliminary reservoir data together with compositional simulators, various depletion alternatives ranging from primary depletion to full pressure maintenance were evaluated. Variables examined in the study included such factors as type of injection fluid and injection-production well configuration. Full pressure maintenance using nitrogen preceded by a hydrocarbon-nitrogen gas buffer in an inverted nine-spot pattern was selected as the most attractive depletion method. This plan was approved by the working interest owners and state regulatory agencies and is currently being implemented.
A Reservoir Engineering Study of an Over-Pressured, Partial Water-Drive Gas Field in Southern Louisiana
Authors: Sharpe G. F. , Van Kirk C. W. 
Published: December 2007

ABSTRACT
The purpose of this paper is not just to present a case history, but also to provide guidelines for performing a reservoir study, and in particular, a material balance analysis. The study involved manipulating a complex material balance equation into forms which isolated certain input parameters. The forms were used graphically not only to estimate the OGIP, but also to verify those parameters used in the analysis. Production decline curves were used in conjunction with the material balance equation to predict future reservoir performance. Theoretical recovery calculations justified the future predictions.
Steam Generation Using Multi-Solids Fluid Bed Combustion Technology For Heavy Oils And Tar Sands Recovery
Authors: Jones Oscar , Britton Michael W. 
Published: December 2007

ABSTRACTConoco is successfully operating a prototype 50 MMBTU/hr., solid fuel-fired, Multi-Solids Fluid Bed Combustor (MS-FBC) to generate 80% quality 2450 psig steam for tar sands recovery from the San Miguel-4 formation in Maverick County in South Texas. The facility is designed to bum high ash coal or high sulfur petroleum coke with environmentally acceptable emission levels of SO2, NOx CO and particulates. More than 8,000 hours of on-line operation have been logged since startup of the fluid bed combustor in January 1982.This paper describes the selection process and criteria used by Conoco in selecting this technology, the key process design considerations and comparative economics with conventional oilfield steam generators. It also discusses the overall system performance and plant modifications which have contributed to improvements in the operability and reliability of the fluid bed combustor steam generator.
Analysis of Five Field Tests of Steamdrive Additives
Authors: Doscher T. M. , Kuuskraa V. A. , Hammershaimb E. C. 
Published: December 2007

Abstract
CLD Technology, Inc. is developing additives to steam which are intended to increase both the economics and the amount of oil recovered in steam injection operations. CLD's initial project was started under a contract with the U.S. Department of Energy in October 1979 for the express purpose of developing and demonstrating the efficiency of "foam blocks" to increase the efficiency of the steam drive.
After extensive laboratory research and development and five field tests, it can now be concluded that the efficiency of the steam drive can indeed be increased in particular reservoirs by the use of the proper additives.
Continued research has demonstrated that the particular additives being developed do alter injection profiles and increase the ability of steam to transport the heated crude oil. Employing a hypothesis concerning the mechanism by which oil is displaced by steam, superior additives have now been developed based on the results of laboratory screening tests.
Field Application of an Additive Containing Sodium Metasilicate During Steam Stimulation
Authors: Mbaba P. E. , Caballero E. P. 
Published: December 2007

ABSTRACT
This paper describes the successful application of an additive consisting mainly of sodium metasilicate in a steam soak operation. Numerous wells tested with a small concentration of the additive responded favorably. Laboratory testing of the additive has established that the alkaline nature of the additive is most effective under prolonged exposure to acidic crude at high temperatures.
Proppant Scheduling and Calculation of Fluid Lost During Fracturing
Authors: Crawford H. R. 
Published: December 2007

ABSTRACTWhen a well is to be fractured, it is helpful to have a quick accurate method to: determine the amount of frac fluid needed without wasteful overdesign, and toestablish an efficient proppant schedule which simultanteously provides high fracture conductivity, long propped lengths and low odds of a screenout.An approach to this type of frac design is presented which uses the following equation. (1)A=V/(W+3CT0.5),    sq  ft
Compressed Air Energy Storage (CAES) in an Aquifer—A Case History
Authors: Istvan J. A. , Crow C. V. , Pereira J. C. , Bakhtiari Hushang 
Published: December 2007

ABSTRACT
The CAES aquifer experiment is a research project which draws its basic knowledge from natural gas storage in aquifers. It does however pose problems of a typical nature, namely the properties of the storage product which has a higher viscosity than natural gas, the need to cycle daily rather than seasonally and the higher temperature requirements. This paper summarizes the test activities that are being conducted at the Pittsfield Aquifer Test Site, concerning the field evaluation of a typical aquifer for storing and cycling compressed air under conditions approaching those existing in a full scale CAES operation.
1982: A Precipitous Decline, The Service Company, Bidding and Integrity
Authors: Ely J. W. 
Published: December 2007

ABSTRACT
From 1979 to 1982, the oil industry experienced a continual rise in the rig count. This ever expanding number of rigs caused the service company industry to undergo rapid expansion both from the standpoint of people and equipment. It was obvious that many of the companies looked at an ever increasing, upward spiral and planned expansion and requirements on that continued growth. The decline in rig count, which actually started in late 1981, was even more drastic than the upward spiral. Many service companies and suppliers for those service companies who had become highly leveraged found themselves in a very precarious position. In order to capture an ever declining market, many service companies resorted to extreme price cutting on available jobs. An examination of the profits of five representative companies during the good years is evaluated and compared to the profitability of companies during 1982 and early 1983. The response of both the service companies and the oil companies in a survival mode are evaluated. The keynote of the paper will be directed toward the free enterprise system, profit motivation, and ultimately, the survival of the oil service industry as we now know it.
Fracturing Operations in a Dry Geothermal Reservoir
Authors: Rowley J. C. , Pettitt R. A. , Hendron R. H. , Sinclair A. R. , Nicholson R. W. 
Published: December 2007

ABSTRACT
Fracturing and completing deep wells in hot, non-porous crystalline basement rock challenges conventional equipment use, procedures, and techniques common in oil and gas and normal geothermal completions. Fracturing operations at the Fenton Hill, New Mexico, Hot Dry Rock (HDR) Geothermal Test Site initiated unique developments necessary to solve problems caused by an extremely harsh downhole environment.
Two deep wells were drilled to approximately 15,000 ft (4.6 km); formation temperatures are in excess of 600°F (315°C). The wells were drilled during 1979-1981, inclined at 35 degrees, one above the other, and directionally drilled in an azimuthal direction orthogonal to the least principal in-situ crustal stress field. The pair of wells form the injection and production wells of an energy extraction system which will be unique in reservoir development.
The test site is located near the flank of a young silicic composite volcano, the Valles Caldera, in the Jemez Mountains of northern New Mexico. The deeper well was planned as the cold water injection hole; as such, it may be cooled from the static, conduction geothermal gradient to as low as 80°F (25°C). The upper, production well will be heated to over 500°F (260°C) along its entire length. The well pair has been designed to be a closed loop, heat-extraction system formed with hydraulic fracture connections between the 1200 ft (370 m) vertically-spaced wells. These production conditions, and the in-situ formation temperatures, strongly constrain all completion hardware, cementing formulations and procedures, and fracturing operations.
Hydraulic fracturing experiments to connect the two wells have used openhole packers, hydraulic jet notching of the borehole wall, cemented-in isolation liners and casing packers. Problems were encountered with hole drag, high fracture gradients, H2S in vent back fluids, stress corrosion cracking of tubulars, and the complex nature of three-dimensional fracture growth that requires very large volumes of injected water. Two fractured zones have been formed by hydraulic fracturing and defined by close-in, borehole deployed, microseismic detectors. Initial operations were focused in the injection wellbore near total depth, where water injection treatments totalling 51,000 bbls (8,100 m3) were accomplished by pumping through a cemented-in 4-1/2-in. liner/PBR assembly. Retrievable casing packers were used to inject 26,000 bbls (4,100 m3) in the upper section of the open hole. Surface injection pressures (ISIP) varied from 4,000 to 5,900 psi (27 to 41 MPa) and the fracture gradient ranged from 0.7 to 0.96 psi/ft.
Successful High-Angle Gravel Packing Techniques
Authors: Nini C. J. , Owen G. W. 
Published: December 2007

ABSTRACT
Gravel packing can be successfully performed on high-angle wells (70°-80°) when special consideration is given to the completion design and details of field procedures and practices. Through analysis and modification of current techniques and research done on full scale models, Chevron experimented with and developed several techniques to successfully gravel pack high-angle wells .
The high-angle gravel packs were performed utilizing the following criteria: solids free completion fluids, low-side perforating, modified screens, combination tools (circulating pack), maximum tailpipe (washpipe)-liner ratios, medium viscosity carrier fluids, maximum pumping rates, and special attention to quality control.
Sand-out pressures, subsequent pack tests, quantity of gravel placed (percent packed volume) and extended flow tests of up to 20 MMCFD have proven the success of the design and procedures implemented.
Hydraulic Fracture Orientation Using Passive Borehole Seismics
Authors: Dobecki T. L. 
Published: December 2007

ABSTRACT
Passive borehole seismometry enables mapping the orientation of induced hydraulic fracture planes by using a triaxial seismometer clamped in the treatment well to map acoustic emissions from the fracture. Presently, the method utilizes only those seismic events attributable to shear failure along the fracture plane which exhibit both compressiona1 and shear wave phases. The fracture azimuth is seen to parallel the polarization of the compress iona1 wave phase. Whereas other geophysical techniques used to determine fracture orientation are principally surface-deployed measurements and, therefore, lose their effectiveness as the fracture depth exceeds 1500-2000 meters, the borehole seismic has worked effectively at 3300 meters in past applications. The method, principally, gives only fracture azimuth as is demonstrated by two examples of field test data.
Prediction of Conditions Necessary for Multiple-Contact Miscibility
Authors: Cohen G. S. , Shirer J. A. 
Published: December 2007

ABSTRACT
This paper describes a method that predicts the minimum amount of enrichment of a hydrocarbon gas with intermediate weight hydrocarbons necessary to achieve a miscible fluid displacement in the reservoir. The method is based on the work of Benham, et.al1 and is an application of their description of the multiple-contact displacement process. The technique requires that compositional analyses are available for the hydrocarbon gas, intermediate weight hydrocarbons, and the reservoir fluid. In addition, a phase behavior simulator must be available to generate the foundation of the method, a pseudo-ternary phase diagram. The method has been used with two light crudes and two intermediate weight hydrocarbon mixtures, and has compared very favorably with laboratory slim tube tests.
Efficiency of a Single-Stage Cuttings Washer With a Mineral Oil Invert Emulsion and Its Environmental Significance
Authors: Jones Maurice , Burgbacher J. A. , Churan Marc , Hulse Michael 
Published: December 2007

ABSTRACT
Questions and concerns about the use of mineral oils to replace diesel in invert emulsion drilling fluids for offshore oil and gas wells have centered on the treatment and disposal of oil wet cuttings. This study, using a modified 20 ml retort procedure, measured the percent retention (w/w) of mineral oil based mud on cuttings from the shale shaker and a single-stage cuttings washer at one offshore Texas well. The modified retort procedure was demonstrated to be a highly repeatable procedure. Retort results were then correlated to more sophisticated laboratory techniques (gravimetric, gas chromatographic, and IR spectrophotometric procedures) with good agreement to two of the three methods. Solid phase bioassays with three marine invertebrates (clam, worm, and shrimp) suggested that seawater washed cuttings were the most environmentally acceptable method. Further considerations suggest that the use of mineral oil-based muds may be enhanced relative to diesel oil-based muds if regulatory relief is achieved.