bluuebunny/crossref_metadata_2025_split huggingface dataset:
Aspects of Oil and Gas Operations on Federal and Indian Lands of Interest to Engineers
Authors: Curtis Charles J. 
Published: December 2007

It is always enjoyable to attend any meeting of the Society of Petroleum Engineers. I am happy to have this opportunity to speak to you because I believe that petroleum engineers can benefit from a better understanding of the Mineral Leasing Act and the regulations that implement the act insofar as these affect or influence your work. The regulations that implement the leasing act are commonly known as the Oil and Gas Operating Regulations. These regulations are officially described as Part 221 of Title 30 of the Code of Federal Regulations. They are printed in a small green booklet which most printed in a small green booklet which most of you have probably seen at one time or other. The requirements of the operating regulations, as specifically set forth in the booklet, or as determined by policy judgments in our various offices, can affect some aspects of your work.
I think it would be appropriate first to discuss the two types of lands, Federal lands and Indian lands, which are subject to the Oil and Gas Operating Regulations. Federal lands generally are classified in two categories, acquired land and public domain lands. Acquired lands are lands to which the Federal Government obtained title by purchase, exchange, condemnation, or private gift. These lands are scattered private gift. These lands are scattered throughout the United States and total about 54 million acres, or about 7.5 percent of the area classified as public percent of the area classified as public lands.
The public domain lands are lands to which the United States has held title since their original acquisition. There are public lands in 30 states, but the large bulk of the lands are located in Alaska and the Western States. You may recall from your history courses some of the purchases and treaties by which the United States obtained most of the lands now described as public domain lands. The Louisiana Purchase in 1803 included among the Western States most of Montana, eastern and central Wyoming, northeast Colorado, and the northern part of Texas. This treaty also included a large part of the area now generally referred to as The "Midwest". The annexation of Texas occurred in 1845 and it is somewhat surprising to realize that this included, among other lands, a strip of land through western Colorado and a rectangular shaped piece of land in Wyoming, south of Rawlins piece of land in Wyoming, south of Rawlins The acquisition of the Oregon Territory in 1846 brought into the Union parts of western Wyoming and Montana as well as what is now Idahos Oregon, and Washington.
Asphaltene Surface Activity at Oil/Water Interfaces
Authors: Sheu Eric Y. , Shields Michael B. 
Published: December 2007

ABSTRACT
Small angle neutron scattering (SANS) dynamic surface tension (DST), dynamic interfacial tension (DIFT), and zero shear viscosity were used to study the surface activity of Ratawi asphaltenes in organic solvents, in the asphaltene/water/toluene emulsions and at the toluene/aqueous solution interfaces. In organic solvents, the kinetic process of micellization and the micellar structure are characterized. Their dependence on asphaltene concentration was investigated. The emulsion droplet structure and their capability in water uptake was tested. Also, the enhancement of surface activity of asphaltenes and its potential applications are briefly discussed.
Solubility and Phase Behaviour of Polyacrylate Scale Inhibitors and Their Implications for Precipitation Squeeze Treatment
Authors: Rabaioli M. R. , Lockhart T. P. 
Published: December 2007

ABSTRACT
The phase behavior of a commercial phosphino-polyacrylate inhibitor (PPAA) in aqueous brine has been characterized as a function of temperature, pH, and the Ca++ and PPAA concentrations. The quantity of precipitate formed has been determined as a function of the same variables. Contrary to expectations, over a range of conditions the yield of phase-separated PPAA was found to be less than 50% and sometimes as low as 5%. Studies on a sample of isolated precipitate show that it has significant solubility even in brines with high Ca++ concentration. Ca++-induced fractionation of the polymeric inhibitor by molecular weight has been identified as the mechanism responsible for both the observed precipitation and re-dissolution behavior. The implications of these results for the optimization of precipitation squeeze treatments are discussed.
Graphical Determination of Oil Recovery in a Five-Spot Steamflood
Authors: Ali S.M. Farouq 
Published: December 2007

Abstract
Calculation of oil recovery by continuous steam injection is generally tedious, even if a computer program is used for this purpose. The present study is directed toward developing a graphical method of computation of oil recovery by continuous steam injection in a five spot pattern. Oil recovery from the steam-invaded zone as well as from the condensate zone ahead of the steam zone is considered in this treatment. Expansion of the steam zone and t temperature variation of density are employe compute the effective flood advance rate for the hot and cold waterflood zones ahead of the steam zone, in which Buckley-Leverett type displacement is assumed to occur. One of the basic parameters involved in the method is the parameters involved in the method is the steamflood sweep efficiency, which is based upon detailed theoretical and experimental investigations. Along with the detailed graphs, the basic equations used are also presented, in case it is desired to use the present method on a digital computer.
The end product of the computation technique presented is a curve of cumulative oil recovery presented is a curve of cumulative oil recovery vs. time. Curves of this type computed by the proposed technique are compared with experimental proposed technique are compared with experimental curves, as well as with values predicted by detailed methods, showing fair agreement.
Introduction
In recent years, steam injection has come to be recognized as an important oil recovery method. Most of the projects have so far utilized cyclic steam injection, which, in spite of its attractive feature of quick return, is basically a formation stimulation type operation marked with a low ultimate oil recovery of 6-15% of the oil in place. For this reason, increased interest is being shown in steamflooding, or continuous steam injection, with operational features similar to those for waterflooding, in order to enhance the ultimate oil recovery.
A member of methods have been proposed for the computation of oil recovery by a steamflood, the most notable being those due to Marx and Langenheim, Ramey, and Willman et al. Recently, Davies, Silberberg, and Caudle presented a method for predicting oil recovery from a five-spot steamflood, in which streamlines were approximated by straight lines radiating from the injection well, and converging to the production well. The present work develops a method production well. The present work develops a method for predicting the performance of a steamflood in a five-spot pattern, employing a combination of Marx and Langenheim's, Willman et al's, Ramey's, and Higgins and Leighton's techniques.
Static and Dynamic Adsorption of Phosphonate and Polymeric Scale Inhibitors Onto Reservoir Core From Laboratory Tests to Field Application
Authors: Jordan M. M. , Sorbie K. S. , Yuan M. D. , Taylor Kate , Hourston K. E. , Ramstad Kari , Griffin Paul 
Published: December 2007

Abstract
In this paper, results from static tests have been used to establish scale inhibitor adsorption mechanisms and levels in consolidated reservoir cores and to rank inhibitors for their adsorption behaviour and, in some cases, squeeze return lifetimes. The purpose of this rapid and simple type of bulk adsorption measurement is to assist in the selection of inhibitors for further coreflooding which should be carried out on a minimum number of inhibitors. A bulk adsorption sensitivity study can be carried out very rapidly compared with carefully carried out reservoir condition core floods. The value of such rapid screening tests is evident although we show that it is not always possible for all factors concerning squeeze lifetime to be determined in this way. It is still often necessary to carry out a much smaller number of reservoir condition core floods for a few (usually between 1 and 3) selected inhibitor products. This is necessary if the dynamic adsorption isotherm, T(C), is to be derived in order to develop the "Field Squeeze Strategy" or for the assessment of formation damage which might occur in the squeeze treatment. A field example of this is presented briefly in this paper although details can be found elsewhere.
A New Binary Surfactant Mixture Improved Foam Performance in Gas Well Production
Authors: Xu Rong , Yang Lin 
Published: December 2007

Abstract
A binary surfactant mixture that can generate stable, high quality foam at insitu conditions has been developed in this study. This paper presents laboratory results of this surfactant system and discusses its application in the gas well production.
We have used Ross-Miles, Waring Blender and Drill-Aid methods to evaluate foamability, half life of foam volume decay, and foam stability. It was found that a mixture composed of THSP, a derivative of Tea Plant, and SDS (sodium dodecyl sulfate) is a desirable aqueous base surfactant foaming liquid. It presents much better foam performance than other surfactants used before. The effects of H2S, salts and surfactant concentrations, condensate and reservoir temperatures on the THSP-SDS mixture in foamability and foam stability are investigated. At insitu conditions, this surfactant mixture is only one that can be used to drain water out from the gas well, and therefore enhanced gas well productivity.
In this paper, we will present chemical compositions of the THSP-SDS, show all the laboratory data and test procedures, and illustrate field application results. Research findings in this work provide useful information for engineers involved in using foam drainage in gas well production.
Alteration of Permeability by Fine Particle Movement—A Water Injectivity Problem
Authors: Asghari Koorosh , Kharrat Riyaz , Vossoughi Shapour 
Published: December 2007

Abstract
Siri field is located off shore of Iran in Persian Gulf. It was discovered in 1972. The field is producing from a formation called Mishrif which is common between Iran and United Arab Emirates. Existence of an active aquifer and other appropriate conditions led to the decision of a water injection program. The design and the implementation of the water injection program was performed by Elf Aquitaine and water injection started in 1984. The sea water from the Persian Gulf was found to be compatible with the formation water and was directly injected into the formation after passing through 10 micron filters. Water injectivity was drastically decreased and it reached from an initial injection rate of 9100 bbl/day to 2200 bbl/day within six years. Because of the severe injectivity loss, the water injection was stopped.
An experimental investigation was undertaken to look into the possible causes of the injectivity loss. Two sets of experimental investigation were undertaken with different objectives in mind. In the first part glass bead packs were used to test the experimental set up and to observe the general behavior of fine particle movement in porous media. In the second part core plug from the field and sea water were used to determine the possible cause of injectivity loss in the field. The experiments were conducted with a range of injection rate of 0.9 cm3/s to 3.1 cm3/s. Particles of bentonite were suspended in the injected water to simulate fine particles migration in porous media. The particles were injected at concentrations ranged from 20 g/1 to 40 g/1. It was observed that the build up in flow resistance was mostly due to the frontal face plugging. Particles of bentonite and alumina were added to the glass beads to study the effect of particles initially present in the glass beads pack medium.
Field and the laboratory data clearly indicate the importance of the water quality in a waterflood project. Experimental data suggest that a smaller size filter should have been implemented to avoid the injectivity loss.
Thermal Recovery Processes and Hydrogen Sulfide Formation
Authors: Hoffmann G. G. , Steinfatt Ingeborg , Strohschein Adelgunde 
Published: December 2007

Abstract
Thermal recovery processes are well established enhanced oil recovery techniques and are widely applied for recovering heavy oil, heavy oil sands, and shale oil.
During thermal recovery the formation of hydrogen sulfide, H2S, including the H2S induced reduction of sulfate to H2S, has to be taken into account in the reservoirs. The mechanisms of H2S formation are not well understood. Therefore, a great variety of experiments was performed, mainly to investigate the formation of H2S in the presence of crude oil under variation of the temperature (250 - 320 °C) and the reaction time. Thus, the reactivity of crude oil in the presence and in the absence of H2S, as well as in the presence and in the absence of ammonium sulfate, (NH4)2SO4, or sodium sulfate, Na2SO4, was examined. An attempt is made to explain the chemical pathways leading to the formation of H2S during thermal recovery methods. The improved knowledge about the H2S-formation during thermal recovery of fossil fuels can contribute to find solutions for its prevention and must therefore be seen from the environmental standpoint of view.
The Efficiency of a DTPA-Based Solvent in the Dissolution of Barium Sulfate Scale Deposits
Authors: Putnis Andrew , Putnis C. V. , Paul J. M. 
Published: December 2007

Abstract
This paper describes kinetic experiments to determine the rate at which Ba ions are mobilized from crystalline barium sulfate into aqueous solution by a solvent in which the active ingredient is a strong chelating agent for Ba ions (DTPA - diethylene triamine pentaacetic acid). The experiments define the temperature dependence and hence the activation energy of the dissolution process, the surface area dependence and most importantly the dependence on the concentration of the DTPA in solution.
In a 0.05M DTPA solution the dissolution rate of barium sulfate is highly temperature dependent with an activation energy of ~45kJ mol-1. This value suggests that the rate is controlled by the desorption of a Ba-DTPA surface complex. Surface complexation is further identified as the key to barium sulfate dissolution by the observation that over the concentration range 0.5M to 0.05M DTPA the initial dissolution rate is inversely related to the DTPA concentration. The activation energy remains unaltered but the absolute dissolution rate is increased. In other words, a 0.05M DTPA solution is more efficient as a solvent than a 0.5M solution. This unexpected result is interpreted in terms of a passivation of the barium sulfate surface by the formation of a surface complex layer at high DTPA concentrations.
Evolution and Development of a Deliverability Improvement Program for Gas Storage
Authors: Maddox T. D. , Sikorski D. L. 
Published: December 2007

ABSTRACT
With the implementation in November 1993 of FERC Order 636, the responsibilities and contractual obligations for a Gas Transmission Company operating Gas Storage have changed. Among these responsibilities is the ability to deliver gas from storage in a timely manner as specified by gas storage contracts.
To ensure that their deliverability obligations are met, a program has been implemented to review well performance and to re-work wells where deliverability can economically be improved. This program is aimed at maintaining or improving deliverability from wells and monitoring their future performance.
Re-working existing wells has proven to be an economically successful method of maintaining deliverability compared to drilling new wells to meet this purpose. Re-working can be broken into two groups of wells: wells that have mechanical problems that need to be corrected or wells that need some type of stimulation treatment. In developing a rework program, several things need to be addressed such as: a candidate recognition program, the design of the work to be performed, execution of that work, and the evaluation of the results obtained along with the economics.
The Deliverability Improvement Program is in its third year. It has developed from a small pilot program to a substantial part of normal storage activities. The purpose of this paper is to review the processes used to find candidates to work on and an evaluation of work performed.
Coiled Tubing Applications for Underground Gas Storage
Authors: Fowler Hampton , Holcombe Don 
Published: December 2007

Abstract
Technological advances in coiled tubing (CT), CT handling equipment, and application techniques have provided new opportunities for the effective, economic use of CT for gas storage and retrieval. This paper presents a review of the CT capabilities that can be used for improving the performance of gas storage wells and discusses applications that could be performed with CT in the near future.
For more than 25 years, coiled tubing has been used as an effective, economic means of performing remedial well services. In response to the demand for better horizontal drilling equipment, the strength and diameter of CT has been increased, while surface equipment and downhole tools have become more sophisticated. CT is also widely used in well servicing after initial completion, especially since declining oil prices have made it imperative that operators find more cost-effective methods of increasing production and reducing maintenance costs. The gas storage industry can effectively take advantage of the many recent advancements in CT technology.
Analysis of Rate Decline Derivatives
Authors: Zhang Wenxia , Grader A. S. 
Published: December 2007

ABSTRACT
This paper describes rate derivative curves of constant pressure tests similar to derivative analysis for constant rate tests. Four rate decline derivatives: Cartesian, log-semi, semi-log, and log-log, are constructed, Typically, the rate derivative curves have some special characters. The specific characteristics of these derivative curves are related to the different flow regimes and various boundary effects. The derivative curves and decline curves can be used for well test interpretation and diagnostic in a similar way to the constant rate tests. Therefore, in some cases nonunique problems in well test analysis are eliminated. In this paper, we consider rate declines of an arbitrarily placed well in various shapes such as a circle, a rectangle, a stringer, and an irregular shape.
Change in Treatment Style Doubles Salem Limestone Production
Authors: Albi James , Rodvelt Gary 
Published: December 2007

Abstract
After redesigning stimulation treatments to include hydraulic fractures with an epoxy-coated sand final stage, Texaco has achieved a two-fold increase in initial oil production from its Illinois Basin wells completed in the Salem Limestone.
Previous treatments conducted in Salem Lime wells included gelled acid with rock salt diverter, and foamed acid jobs. Initial production increases were favorable, but production declined rapidly. Acid-etch tests on Salem Lime cores showed poor conductivity gains. Twenty-seven subsequent sand fracture treatments pumped with an epoxy-coated proppant in the last stage resulted in initial production averaging 60 BOPD per well. The previous treatments averaged an initial production of 24 BOPD per well. The epoxy-coated final stage served to lock proppant in place after wells were placed on production.
This paper presents job designs and case histories showing the benefits of fracture-stimulating the Salem Limestone for production enhancement.
Integrated Approach to Natural Gas Utilisation in the Asia Pacific Region
Authors: Hovdestad Wayne R. , Egbogah Emmanuel O. 
Published: December 2007

Wayne R. Hovdestad and Emmanuel O. Egbogah

Abstract
The rapidly expanding economies in the Pacific Rim have placed increasing demands upon indigenous natural gas supplies in South East Asia and Australia. Competing demands include exports of liquefied natural gas (LNG), domestic consumption, and potential use for enhanced oil recovery (EOR) to extend the useful life of maturing oil fields. An additional competing demand for gas exports may emerge as the interstate pipeline grid is expanded.
Natural gas supplies in South East Asia and Australia are adequate to satisfy the increasing demands associated with economic growth and the desire to use environmentally cleaner fuels. The development of new gas fields, processing and transmissions facilities, however, involves large capital commitments and long lead times. These factors tend to favour staged development to ensure that facilities are fully utilised when placed onstream. This approach can lead to a mismatch between supply and demand depending on the development timing for gas supplies and increases to market demand.
An integrated approach incorporating the evolving nature of gas demands and discrete physical supplies would provide a means to mitigate against potential mismatching of supply and demand. The consideration of the evolving nature of gas demands could promote economically beneficial changes to gas field development. The development of high carbon dioxide (CO2 content gas fields has been slowed by the lack of a market for CO2. Utilisation of by-product CO2 for EOR could improve development economics, thus facilitating earlier development of gas supplies to satisfy gas demands including domestic use and LNG exports. End users would also benefit from the assurance that gas supplies would become available as needed. The maturity and increasingly complex natural gas industry in the Asia Pacific Region has led to a qualitative change. The model of single projects to satisfy single markets is no longer valid. The current environment is more dynamic, creating the need to anticipate changes to market demands and to find value-added markets for by-products. The integrated approach to gas utilisation discussed in this paper presents a new model more appropriate to the gas industry existing today in the Asia Pacific Region. This approach is particularly significant to widely discussed proposals for an Asia Pacific energy grid extending to Australia. In order to proceed, there must exist specific driving factors and stand alone economic merit to each segment in view of the high capital costs. The benefits of a completed system are often long deferred and hence of limited utility when actual project financing is to be obtained.
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