高梁の精白度と單位體積中の重量,單位重量中の體積,單位重量中の粒數及びカタラーゼ作用に就て實驗した。カタラーゼ作用は精白の進むに從つて作用を減じ,特に0-2, 6-10, 16-18時間の3點に作用を急激に減ずる事を知り得た。
本研究は主任研究員飯高一郎博士,並びに天野久氏の御指導を受け,又精白には山崎眞吉,吉兩氏の援助を受けた。此處に深甚なる感謝の意を表す。

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In this paper, the adaptability of Kozeny's equation was discussed on the relationship between permeability, porosity and internal surface area. The method of determination of surface area as employed in this work result in the measurement of physical adsorption of nitrogen, using gaschromatography, with the aid of the theory of isothermal adsorption by Brunauer, Emmett and Teller (BET).
In this experiment, the surface area of rocks showed fairly large values of about 27 to 51.1 square meters per cubic centimeter of pore volume.
Kozeny's constants were calculated with permeability and surface area of each rock. These constants were by far larger than 5, as determined theoretically. However, it was believed that the Kozeny's equation appries when it was corrected by roughness for surface.
It was also shown that the permeabilities might be related with the surface areas for unit pore volume.

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Pore size distribution is one of the most important reservoir rock properties. The purpose of this report is to calculate and evaluate pore size distribution from capillary pressure curves using the centrifuge method.
The core samples used in this experimental work were Berea Sandstone, Abu-Dhabi Dolomite and Japanese Sandstone. Reservoir rocks were frozen using liquid nitrogen and small core plugs were cut and recovered from them.
Capillary pressure of small core plugs was measured using the centrifuge method. Pore size distribution was calculated and evaluated from their capillaly pressure curves.
After analyzing the graphical representation of these data, the following points are reached:
(1) In Berea Sandstone, the slopes of capillary pressure curves were very steep and most of pore radii distributed 4-5μm.
(2) In Abu-Dhabi Dolomite, the slopes of capillary pressure curves were relatively steep and pore radii distributed narrowly.
In addition, irreducible water saturations were low. This is due to the nonwetting characteristic of Dolomite with respect to water.
(3) In Japanese Sandstone, the slopes of capillary pressure curves were relatively gentle and pore radii distributed widely.
In addition, irreducible water saturations were high. This is due to the wetting characteristic of Sandstone with respect to water.
The centrifuge method for the determination of capillary pressure and pore size distribution is proved to be very effective. This is mainly due to the repeatability in conducting capillary pressure experiments and the number of cores that can be tested at the same time using this method.

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It has been studied to develop a apparatus for analysis of core, in which permeability, porosity, and other physical properties could be measured under high confining pressure simulated deep reservoir condition.
In this apparatus, the confining pressure was applied to a maximum value of 500kg/cm² and internal fluid pressure could be kept in constant to common used value of 350kg/cm² by two pressure regulators. The pressure difference of both sides of core was measured by electrical transmitters of Rosemount Eng. Co. The flow rates of gas were measured by soap film meter.
In the results of these experiments the following relation was observed between permeability and effective stress of each core. When confining pressure was much higher than fluid pressure, the permeability reductions were propotional to the confining pressure. On the other hand, after the fluid pressures reached to a value of about 200kg/cm² in effective stress, the permeability increased and its value might be twice compared with original one.
These results have implied that permeability was not only a function of effective strese but also depended on fluid pressure in core.

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However many quantitative experiments have been studied on determination of quantities of paraffin troubled materials in crude oils, they were not enough to decide quantitatively the troubled deposits in statical conditions. The cold point precipitation method was very convenient and practical one, but might be not precise.
In our study, consequently, the cold precipitation and filtration processes were applid at each temperature for the purpose.
In these results, troubled paraffin deposits were scarcely contained in non paraffin crude oils as Sarukawa 7(I), 37(IIa), and were less than one percent even 0°C. In comparison with these, Fukubezawa 6, 23 crude oils have 3 to 8 percents at 5°C.
These deposits were analysed by infrared spectrometer. As the results, it was recognized that the saturated paraffinic hydrocarbons might be gradually increased with lowering temperature. The other way, aromatic compounds might be decreased with lower temperature.

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It is an important problem to determine the pore size distribution in porous material in order to understand the mechanism of fluid flow in enhanced recovery of oil.
For the purpose, we had developed a simple apparatus to be able to measure the distribution of macro-pore radii by means of volumetric mercury displacement.
The apparatus is mainly consisted of a sample holder, a micro-burette, a monometer and a mercury reserved bulb.
Prior to the measurement, the holder with a sample and the burette were evacuated, and then the sample was immersed into mercury under the balance of zero pressure between internal and external of pore. The displacement volumes of mercury were measured by the micro-burette when the mercury was gradually subjected to varying external pressure from 0.06 atm (6×10³ Pa) to 1.6 atm (1.6×10⁵ Pa).
From the experiment of the Berea sandstones, the following results were obtained:
(1) This apparatus can be used for the measurement of pore size distribution of a rock which will be considered having a bundle of macro-pore capillary tubes larger than 47×10^-5cm in radius.
(2)The permeabilities calculated from the Burdine's equation by using the distribution function are directly proportional to the air permeabilities measured by a fundamental core analysis.

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けいそう土溶着プレートに固定相として種々の分子量のポリエチレングリコール(PEG)を含浸させてTLCを行なった.R_f値のほか,薄層(単位面積あたり)に含まれるPEGの量および移動相の量を測定し,これらの値をMartin式に代入して試料溶質の分配率(K_t)を計算した.この値をバッチ法で測定した分配率(K)と比較したところ,K_t/Kの比(分配効率)は11～55%であって,PEG分子量の大きいほど分配効率は大であった.K_tとKに差異が生ずるのは薄層担体(吸着剤)とPEGの相互作用,ならびにTLCでは溶質がPEG-移動相間に溶解平衡に達しないことが原因であるとして説明ができる.

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ベンズアルデヒドおよびその誘導体(一置換体)の2,4-DNPH (14試料)について次の二次元展開TLCを行なった.
(1)キーゼルグール薄層を25%N,N-ジメチルホルムアミド-アセトン溶液に浸し,シクロヘキサン-エーテル(7:3)で展開した.(2)同じ薄層を10%テトラリン-石油エーテルに浸し,90%メタノール-酢酸-ベンゼン-テトラリン(10:1:1:1)で展開した.得られたはん点は5%水酸化カリウム-エタノール溶液を噴霧して検出した.
試料がプロトン供与体の置換基を持つ場合,(1)では低いR_f値,(2)では高いR_f値を示し,またその他の試料にあっては逆の挙動を示した.そのためはん点は各試料の極性に応じて薄層面上に順序よく位置し,異なる置換基を持つ試料の相互分離は完全であった.
同じ置換基をもつ試料については概して相互の分離は困難であったが,o-置換体のうちその官能基が分子内水素結合をするものにあっては他のm-, p-置換体より高いR_f値を示し,そのため分離が可能であった.分子内水素結合の存在についてはIRスペクトルで確かめた.

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This study is a basic resarch which has been conducted to investigate the effect of oil recovery by nonionic surfactant flooding under the low concentration of the same. For the purpose, two kinds of surfactant were selected as samples. One of them was polyethylene glycol-polypropylene glycol ether and the other was polyethylene glycol-nonylphenol ether.
In the first type, polyethylene glycol-polypropylene glycol ether, we prepare chemicals, which have various mole numbers of ethylene oxide and molecular weight of polypropylene. Concerning their low concentration, the interfacial tension between crude oil and oil recovery efficiency were measured at every temperature.
From these results, we recongnized extremely low interfacial tensions and higher recovery of residual oil when molecular weight of polypropylene glycols were 3, 000 to 4, 000 and ethylene oxide contents were 30 to 40 percent at 30°C to 40°C of test temperature.
In the second type, nonylphenol ether, the lowest interfacial tensions were obtained at 9 to 10 polymerized degrees of ethylene oxide in these surfactants, but the most recoverable efficiency was shown at 7 to 9 polymerized degrees. We could not get the clear relationship between interfacial tension and recovery efficiency in this type of surfactant.

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In this paper, a discussion is presented on the steam-flood performance, the residual oil saturation and the change of recovery owing to oil viscosity differences by steam injection in a reservoir model.
The reservoir model was made of steel pipe 2 inches in diameter and 1m in length packed with silica sand and filled with oil.
In the experiment, the flow performance of oil displacement was shown in three stages. The first one was distilled oil bank which was the end of the oil. The second one was a water bank following the oil which showed a constant flow rate and its water-oil ratio was about 3 to 4. Behind the water bank, the steam front just came in contact with it at the third stage. The flow rate suddenly increased just before steam broke through. The water-oil ratio after the break-through was about 20 to 40.
The residual oil saturation was about 10% in the water bank just ahead of the steam front and gradually increased to 50% toward the distilled oil bank. Behind the steam front, the residual oil saturation was constant.
The oil recovery was increased from 80 to 90%, depending on the decrease of viscosity.

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In this paper, we studied the effects of the chemical structure and compositions of polymer and brine on the flow properties with the aim of mobility control. Five kinds of partially hydrolyzed polyacrylamides were used as polymer samples. We used brine which contained mono-valent (Na⁺, K⁺) or divalent (Mg²⁺, Ca²⁺) ions.
We measured the flow properties of polymer solutions as apparent viscosity, screen factor, resistance factor and residual resistance factor and discussed the relation between each other. The results were as follows:
(1) The resistance factor, residual resistance factor and screen factor, respectively, increased with a polymer molecular weight increase. From these results, it was confirmed that the resistance factors had a positive correlation with the screen factors.
(2) The resistance factor and apparent viscosity decreased with a brine concentration increase. These behaviors become extremely remarkable in divalent ion solutions. However, the screen factors decreased relatively little and the residual resistance factors were almost constant in these brines.
(3) The resistance factor increased at a frontal velocity of over 5ft/day, but there was a reverse tendency at a rate less than 5ft/day.

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