bluuebunny/crossref_metadata_2025_split huggingface dataset:
History Of The Formation Of An Oil Spill Contingency Organization
Authors: Barker Charles D. 
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.

APRIL:
Southern California - Petroleum Contingency Organization (SC-PCO) was formed as an unincorporated joint venture in April, 1976 by the Petroleum Co's. involved in the Federal Leasing program of the Outer Continental Shelf. Operating companies included (12) Arco, Texaco, Getty, Shell, Gulf, Marathon, Mobil, Challenger, Std. of Cal., Exxon and Champlin.

MAY:
Services of Chas. D. Barker were contracted for on May 17, 1976 as Gen. Mgr. Initial funding of $5,000/Operating Co. - $60,000 was deposited late May. Offices were acquired, furnished and moved into on June 1. Car leased, secretary hired and fully operational on June 7th.

JUNE:
Over 1/2 Million dollars worth of equipment on order by July 1st. Space acquired at Pier 200 - Wilmington for storage of equipment, (security, cranes and fork trucks on 24 hr. basis). Placed order for 050 Cyclonet. Placed order for 050 Cyclonet. JULY: Cash Call placed on Participants July 8th ($600,000). Two Mark II Skimmers arrived on site July 8th. Two Vikoma Sea Packs arrived on site July 21st. Telecommunications Task Force has been busy past two months. Negotiations for Black Jack Mtn.- Catalina is underway. Hired CPA and accounting firm.

AUGUST:
Field tested Acme Skimmers purchased air compressor for double purchased air compressor for double diaphram pumps. Field checking all gear for training to start early Sept. Aqua Contractors will perform training of other contractors. Ordered 150 Cyclonet (pair) at a cost of $300,000 for delivery Jan. 1, 1977. Hired legal counsel.

SEPT.:
Placed equipment on display (600 people) at Alameda Staging Service, Inc. people) at Alameda Staging Service, Inc. Made second contact with Navy in regard to Telecommunications on San Nicolas Island. Met with Mr. Shamback and USGS staff on Sept. 20th outlining equipment available - response times and proposed training programs. On Sept. 27, 28 and 29th conducted training programs on Vikoma Sea Pack.
Statistically Designed Oil Dehydration Tests
Authors: Bowman R.W. , Burton W.D. , Pryor J.A. 
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.

Abstract
Shell has used statistically designed bottle tests for a number of years to optimize crude oil dehydration systems. A brief review of important parimeters in crude oil dehydration is reviewed plus the statistical design method and the method of data evaluation is discussed.

Introduction
Oil production in the U.S. usually produces normal emulsions (water-in-oil) with some reverse emulsions (oil-in-water) found associate with thermal and chemical floods. In the strict thermodynamic sense, the coalescence of droplets in a stable system is accompanied by an increase in Gibbs free energy. Coalescence of a stable system will not occur spontaneously as only a decrease in free energy will occur naturally. Conversely, an unstable emulsion would separate spontaneously if given sufficient time. However this time might be weeks, so in a practical sense it will be considered as being stable. Since coalescence causes a decrease in the interfacial area and a small increase in interfacial tension which decreases the free energy, emulsions are probably never truly stable in the thermodynamic sense but east as a pseudoequilibrium. pseudoequilibrium. Droplet size of emulsions is very important in oil-water separators as stated in Stokes Law. They are also important in differentiating between an emulsion and a dispersion. Usually emulsion droplets are in the .5 to 50 micron range with an average in the 20 micron range. An arbitrary division would be to class everything above the 100–150 micron range as dispersions.
Emulsions have an emulsifying agent or surface-active agent absorbed at the oil-water interface usually oriented so a monomolecular film is formed. It is these agents which interfere in dehydration. These agents are usually indigenous to the crude oil system. The emulsifying agents include asphaltenes, resins, organic acids, heavy paraffins, various metallic salts, silts, clays, scale and bacteria wastes. Whether a normal or reverse emulsion is formed depends upon whether the agent is more water compatible (hydrophilic) or oil compatible (lipophilic or hydrophobic). According to Bancroft's rule' of thumb, the continuous phase is the one in which the emulsifier is the most soluble.
Isotope Geochemistry In Geothermal Reservoir Studies.
Authors: Truesdell A.H. , Frye G.A. 
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.

Abstract
Isotope geochemistry has contributed greatly to our scientific knowledge of geothermal systems. The near identity of deuterium isotopes of thermal waters and local rain waters has shown that geothermal systems are recharged by rainwaters which circulate deeply for periods indicated by tritium analyses of more than 60 years. Isotope geothermometers utilizing the distribution of 18 between water and dissolved SO4, of 13C between CO2 and CH4, and of 34S between H2S and SO4 have indicated from surface samples temperatures at depth above the range of chemical geothermometers. Isotope studies have indicated that the source of dissolved carbon, sulfur, lead, and strontium in certain systems is rock leaching rather than magmatic contributions. Other components such as 3HE ultimately originate in the mantle, but their immediate source may also be rock leaching.
The role of isotope geochemistry in geothermal reservoir studies is still being developed but shows great promise. Oxygen-18 and tritium studies at Larderello have demonstrated that lateral recharge with young water occurs in parts of the system. Similar recharge in The Geysers has not been demonstrated. Carbon isotopes in CO2 and CH4 suggest that hotter reservoirs exist at Wairakei and Larderello with temperatures above 350 deg. C. Changes in oxygen-18, deuterium, and gas contents with flow rate of Geysers steam have shown that in unexploited parts of the field, steam and liquid water coexist near wellbottoms and most steam is produced by evaporation of liquid when pressures are reduced in exploitation. There are indications of lateral movement of steam with condensation and reevaporation from the center of the field towards the margins, Radon contents also show marked changes with flow rate but interpretation to yield reservoir properties has not been achieved. properties has not been achieved

Introduction
Geochemistry of H, O, C, and S isotopes in the H2O, SO4—, HCO3—, CO2, CH4, H2 and H S of geothermal fluids has broad applications in geothermal reservoir studies. Unlike dissolved salts and gases, oxygen and hydrogen isotopes of water are direct tracers of the water itself and may indicate its origins, movements and subsurface conditions. Isotopic tracers are especially valuable in vapor-dominated systems where salts remain in the reservoir and only steam and gases reach the surface.
Computer-Aided Analysis of Tracer Dispersion in Composite Cores: Tests of Two- and- Three Phase Flow Experiments
Authors: Alvarado V. , Manrique E. , Ponce R. , López P. 
Published: December 2007

Abstract
Tracers are commonly used for monitoring fluid transport in oil and water reservoirs. This paper provides results on tracer dispersion experiments in the so-called composite cores. They were performed under steady-state flow of formation water at Sw = 100% and Sor, and also under conditions of multiphase flow in a water-alternating-gas process (WAG). The composite core was assembled with 6 plugs from the same sandstone formation, having similar geological characteristics. KCl was used as a passive tracer, for which the chlorine concentration was determined by means of electrical conductivity measurements and tritation of the produced water. From the concentration values at different times, breakthrough curves were obtained and analyzed. Porosity and absolute permeability were measured before packing, and a relative permeability curve for the composite core was obtained. This information was used to history match the production curves in multiphase flow experiments. For the tracer result, a commercial simulator and a 2-D stochastic simulator, developed for this purpose, were used to predict the breakthrough curves. For the latter, an estimate of the dispersivity was obtained by fitting the curve with an analytical solution of the 1-D convection-dispersion equation. Multiphase flow results are in good agreement with the mass balance. For WAG experiments, it can be shown that there is intermediate value of the water-to-oil ratio in the feed that results in an optimum in terms of recovery and economics. The analysis shows that the breakthrough curve can be predicted reasonably well for the condition of Sw = 100%. Numerical dispersion turns out to be a difficulty when running the commercial simulator that is naturally overcome in the case of the stochastic simulator. There seem to be effects of saturation on dispersivity as the predictions show.
Study and Application of Weak Gel System Prepared by Complex Polymer Used for Depth Profile Modification
Authors: Wang HongGuan , Guo WanKui , Jiang HongFu 
Published: December 2007

Abstract
This paper provides a weak gel system (WG) prepared by a complex polymer, an organic crosslinker and an additional agent for depth profile modification, which is different from colloidal dispersion gel (CDG) and bulk gel (BG). The gel system can be injected into depth reservoir (injection radius over 60 meters) to generate the plugging in high permeable interval, then the late injected water or polymer can be forced to convert into low permeable zone for increasing swept volume, oil displacement efficiency and oil production. From 1996 to 1999 in China, 45 wells in five polymer-flooding blocks and two water-flooding tracts had been treated by using the gel system in No.1 product, No.3 product and No.9 product of Daqing Oilfield Company. 2000~6300m3 treatment fluid had been injected per well. Average 2.2~103t/day incremental oil production and 13~43.8% decreasing overall water cut were obtained. The successful rate reached 91% and input/output ratio was 1:8. Through the evaluation of the numeral simulation method, the final recovery efficiency can be increased from 1% to 3% by using the technology recommended by this paper.
Decision-system of selecting well, job design and numerical simulation method are introduced here.
Chemical Control Techniques for the Paraffin and Asphaltene Deposition
Authors: Dong Lijian , Xie Huizhuan , Zhang Fusheng 
Published: December 2007

Abstract
Paraffin related problem appears through out the production process of nearly all kinds of crude oils all over the world. It also appears in the dewatering process and the long distance crude oil transportation. In Daqin Oil Field in northeastern China, 150 million RMB is spent on the cleaning up the paraffin deposition (including the total expense on cleaning up the paraffin deposition on various surfaces of production equipments by the mechanical, thermal, chemical etc. methods).
Just as the same, asphaltene deposition problem is also encountered in the oil production process. This paper focus on the discussion of paraffin deposition and its chemical control technique.
The paper introduce the latest research and development of chemical additives (DQ, KOW, AOA, ZHJ) for the control of paraffin and asphaltene and their successful application on 2000 wells in Chinese oil fields. In the oil field application, chemicals were added into the oil tube or annular space, or squeezed into the oil formation so that the deposition of paraffin and asphaltene was inhibited. Oil wells treated with DQ, KOW, AOA, ZHJ were all kept on long time normal production, the times of repairing equipment and shutting up oil wells were greatly reduced. Also the productivity was enhanced and the production cost was decreased. Annual economic benefit by using of this chemicals was about 21, million RMB.
The design of paraffin inhibitors in the paper was based on the theory of co-crystallization, the theory of surface chemistry and colloidal dispersion chemistry. DQ, KOW, AOA were thus designed and have satisfactory properties. The paper also discuss the mechanism of paraffin deposition inhibition.
Study and Application of the Viscosity Reducer Used in Production of the Viscous Crude Oil
Authors: Xie Huizhuan , Zhang Fusheng , Dong Lijian 
Published: December 2007

Abstract
According to the property of the viscous crude oil in China, ORV (oil-base viscosity reducer) and HEA (water-base viscosity reducer) have been developed. ORV oil-base viscosity reducer which is composed of high molecular weight polymer, surfactants and other additives etc., has a good viscosity-reducing effect for the viscous crude oil with low or medium viscosity, at the dosage of 100 to 300mg/kg, viscosity was reduced by 60% to 80%, in the same time, has a good pour point-reducing effect for high pour point crude. HEA water-base viscosity reducer which is composed of surfactants, stabilizer and other additives etc., has a very good viscosity-reducing effect for the viscous crude oil with high viscosity, at dosage of 50~200mg/kg, viscosity was reduced by above 99%. Above-mentioned two reducers have already used in Jidong, Liaohe and Shengli etc. oilfields, a better application effect and a tremendous economic benefit (according to the incomplete statistical data, that of ORV is 13.5 million yuans RMB per year, and ratio of input to output is 1:11; that of is 20 million yuans RMB per year, and ratio of input to output is 1:26.2) were abtained. And moreover, HEA viscosity reducer has a good high temperature-tolerant ability and can be used as the spearhead chemical agent for steam soak, ORV viscosity reducer has pour point-reducing and wax-inhibiting functions.
Effect of IOR/EOR Chemicals on Interfacial Rheological Properties of Crude Oil/Water Systems
Authors: Lakatos I. , Lakatos-Szabó J. 
Published: December 2007

Abstract
Interfacial rheological properties of different Hungarian crude oil/water systems were determined in wide temperature and shear rate range and in the presence of inorganic electrolytes, water-soluble polymers, non-ionic tensides and alkaline materials. The detailed laboratory study definitely proved that the interfacial rheological properties are extremely sensitive parameters towards the chemical composition of immiscible formation liquids. Therefore, comparison and interpretation of the interfacial rheological properties may contribute significantly to extension of the weaponry of the reservoir characterization, better understanding of displacement mechanism, development of more profitable EOR/IOR methods, intensification of surface technologies, optimization of pipe line transportation and improvement of refinery operations. It was evidenced that the interfacial rheology is an efficient and powerful detection and differentiation technique, which may enhance our knowledge on formation, structure, properties and behavior of interfacial layers. Thus, it will probably accelerate significantly the progress not only in oil recovery but also in all areas of colloid science and technology.
Effect of Brine Composition and Alkaline Fluid on the Permeability Damage of Limestone Reservoirs
Authors: Bagci Suat , Kok Mustafa V. , Turksoy Ulas 
Published: December 2007

ABSTRACT
Secondary and tertiary recovery processes can lead to severe and permenant reductions in permeability because of interactions between injected fluids and the reservoir rock. Permeability damage was suspected as a factor contributing to post completion production declines observed during waterflooding of an unconsolidated limestone.
This study summarizes the laboratory studies undertaken to evaluate and understand permeability damage in limestone reservoirs. The influence of brine composition, salinity of alkaline fluid and injection rate on permeability damage were evaluated in consolidated and unconsolidated cores. Effluent pH and Cl concentrations were measured at the outlet of the porous medium. Brines were prepared with sodium, calcium and potassium salts (NaCl, CaCl2, KCl). High pH values in produced water caused the permeability reduction and consequently the pores were plugged and formation damage was observed.
In alkaline flooding experiments, permeability reduction was observed as a result of high pH alkaline fluids (NaOH, NaSiO4). The permeability reduction was decreased using NaCl, CaCl2 and KCl mixtures and high oil recoveries were obtained. Suspended solid particles were released and moved with injection water as a result of Cl concentration below the critical salt concentration caused the permeability reduction and the formation damage was occurred.
Compositional Dependence of Reservoir Wettability
Authors: Muhammad Z. , Rao D. N. 
Published: December 2007

Abstract
The purpose of this work is to carry out a systematic study of the effects of crude oil, brine and rock compositions on formation wettability. Degree of wetting depends on the dynamic contact angle measured in a mode that enables movements of the three-phase contact line.
Knowledge of formation wettability is important in primary, secondary, and enhanced oil recovery operations. By varying compositions of crude oil and brine, and using crystal surfaces of different mineralogy and roughness, we can get a better understanding of the rock-fluid interactions in reservoirs.
The Wilhelmy Plate technique is being used in this study to measure adhesion tension (which is the product of interfacial tension and cosine of the contact angle) at the solid-liquid interface; a microbalance is connected to a computer which detects the change in force as the solid surface travels through oil and brine interfaces in advancing and receding modes. The water-advancing and water-receding contact angles can then be calculated from the adhesion tensions by making independent measurements of the fluid-fluid interfacial tensions.
The method is used to study pure hydrocarbons and synthetic brines of different concentrations and the wetting behavior is used to study Yates field crude oil, brine and rock interactions. Polished surfaces of glass slides and dolomite are used to simulate the reservoir rock surface. An ethoxy alcohol surfactant, which is being used in the field for enhancing oil recovery, was used to quantify its wettability effects.
The results of the systematic experimental investigation of the effects of practical variables on wettability are presented. It is found that interactions between surface active agents at the interface of two fluids have an effect on wettability alteration. The composition and concentrations of different organic and inorganic chemical species have a major effect in making a reservoir oil-wet or water-wet.
Cost Saving Benefits of Using a fully Bi-directional Tractor System
Authors: Henderson Bruce , Hopwood Chris , Hamilton Cameron , Garies Jim 
Published: December 2007

Abstract
A new wireline tractor system has been developed that is the first to be fully bi-directional in both speed and pulling force. It was used on a number of high angle wells in Alberta and Saskatchewan and delivered both cost saving and risk saving benefits to the operator.
Comparison of Chemical Steam Floods through Vertical and Horizontal Wells
Authors: Shedid Shedid A. , Abbas Al-Abbas A. 
Published: December 2007

Abstract
Laboratory investigations and field applications have proved steam drive to be an effective enhanced oil recovery method for reservoirs of moderate and heavy oil viscosity. This experimental study was undertaken to investigate, combine and compare the performance and productivity of water, steam, alkaline steam, surfactant steam, and surfactant alkaline steam floods through vertical and horizontal wells. To achieve the objectives of the study, two experimental models (vertical and horizontal) are designed and built. Identical porous media, reservoir fluids (crude oil and formation water), steam, chemicals, and injection/production conditions are used and/or applied.
The results of the study showed that horizontal wells are better candidates for waterflooding than vertical ones, when the same pore volume of water are injected in the reservoir. Steam and chemical steam (alkaline steam, surfactant steam, and surfactant alkaline steam) floods recovered more oil when applied through horizontal wells than through vertical ones. In addition, chemical steam floods recover more oil than conventional steam drive for both applications of vertical and horizontal wells. The increment of oil recovery due to application of horizontal wells instead of vertical ones may be 10.27 % IOIP for steam flood and almost 17.7 % IOIP for surfactant alkaline steam flood.
The displacement efficiency of oil recovery through horizontal wells is higher than that through vertical wells for steam flood by almost 25 %, for alkaline steam flood by almost 33 %, for surfactant steam flood by almost 37 %, and for surfactant alkaline steam flood by almost 48 %. The proposed techniques of chemical steam floods have important implications for improving oil recovery from current water flood and steam projects, since they combine the advantages of both chemical and thermal recovery methods.
Understanding Chemical-Potential-Related Transient Pore-Pressure Response To Improve Real-Time Borehole (In)Stability Predictions
Authors: Tare Uday A. , Mody Fersheed K. , Mese Ali I. 
Published: December 2007

Abstract
Chemical potential related borehole (in)stabilities in the field are predominantly time-dependent. With the intention of developing a real-time wellbore (in)stability modeling capability, experimental work has been undertaken to investigate the role of chemical potential of drilling fluids on transient pore pressure and time-dependent rock property alterations of shale formations. The current work presents the concept and discusses the results of these undertakings.
The experiments using a Pore Pressure Transmission Test (PPT) apparatus expose formation (shale) cores under simulated downhole conditions to various salt solutions and drilling fluids. The uniqueness of this study comes from the fact that time-dependent alterations in the pore pressure, acoustic, static properties and strength of formations subjected to compressive tri-axial stress are recorded during the PPT experiments. This eliminates the anisotropy-associated differences obtained when different samples are used to determine the relationship between these characteristic parameters of shale formations. This comprehensive testing program will enhance our understanding of the relationship between acoustical, mechanical and chemical properties of shale as a function of time when exposed to a drilling fluid.
The main objective of this effort is to translate the results of the PPT tests to actual drilling conditions. Wherein the formation-drilling fluid chemical potential model would be validated and updated in real-time to predict borehole (in)stabilities.