2016_海外油气资产评估模板(勘探类)
广东省深圳市2020年高一上学期政治期中考试试卷B卷
广东省深圳市2020年高一上学期政治期中考试试卷B卷姓名:________ 班级:________ 成绩:________一、单选题 (共25题；共50分)1. （2分） (2017高一上·徐州期中) 网上购物，就是通过互联网检索商品信息，并通过电子订购单发出购物请求，之后通过支付、发货等一系列环节完成交易的购物形式。
商家一般通过快递方式发货，买方多是通过担保交易的方式货到付款，在这种交易方式下（）A . 货币产生了新的职能B . 商品流通中所需要的货币量减少了C . 货币仍然执行流通手段职能D . 生产者与消费者的关系发生了变化2. （2分） (2018高一上·双鸭山月考) 经济学家有一个假设:用直升机在一个封闭的“迷你国”上空抛撒现金，使这个“迷你国”中的每个人持有的现金都增加了1倍，结果不是每个人都多得到1倍的商品，而是该国的物价总水平上涨1倍。
上述假设告诉我们的经济生活道理是（）①纸币发行必须以流通中所需要的货币量为限度②纸币的购买力取决于政府的意志③国家过多发行纸币会导致通货膨胀④该国货币升值A . ①②B . ③④C . ①③D . ②④3. （2分） (2019高一上·衢州期中) 近五年来，我国消费对经济增长的贡献率由54. 9%提高到58. 8%，品位消费成为消费的主流，服务业比重从45. 3%上升到51. 6%，成为经济增长主动力。
这意味着（）①我国的经济结构不断趋于优化②服务业已成为社会经济发展根基③消费对经济的发展起基础性作用④第三产业日益成为国民经济的支柱A . ①③B . ①④C . ②③D . ①②4. （2分） (2017高一上·江海期中) 预计到2013年，全球将有2．14亿户家庭接收高清电视节目，而2008年这个数字为4200万户。
没有高清电视生产的大发展，就没有人们对高清电视的强烈向往，这体现了（）A . 生产为消费创造动力B . 生产决定消费方式C . 消费也是生产的动力D . 生产决定消费的内容5. （2分） (2018高一下·榆社期中) 2017年，华为、格力、海尔、美的等近两千家企业向全社会郑重承诺，全面提升产品和服务质量，助力中国发展迈入质量时代。
ASTM D1298
Designation:D1298–99(Reapproved2005)Designation:Manual of Petroleum Measurement Standards(MPMS),Chapter9.1Designation:160/99An American National StandardStandard Test Method forDensity,Relative Density(Specific Gravity),or API Gravityof Crude Petroleum and Liquid Petroleum Products byHydrometer Method1This standard is issued under thefixed designation D1298;the number immediately following the designation indicates the year oforiginal adoption or,in the case of revision,the year of last revision.A number in parentheses indicates the year of last reapproval.Asuperscript epsilon(e)indicates an editorial change since the last revision or reapproval.This standard has been approved for use by agencies of the Department of Defense.1.Scope1.1This test method covers the laboratory determination using a glass hydrometer,of the density,relative density (specific gravity),or API gravity of crude petroleum,petroleum products,or mixtures of petroleum and nonpetroleum products normally handled as liquids,and having a Reid vapor pressure of101.325kPa(14.696psi)or less.1.2Values are measured on a hydrometer at either the reference temperature or at another convenient temperature, and readings corrected to the reference temperature by means of the Petroleum Measurement Tables;values obtained at other than the reference temperature being hydrometer readings and not density measurements.1.3Values determined as density,relative density,or API gravity can be converted to equivalent values in the other units at alternate reference temperatures by means of the Petroleum Measurement Tables.1.4Annex A1contains a procedure for verifying or certify-ing the equipment for this test method.1.5This standard does not purport to address all of the safety concerns,if any,associated with its use.It is the responsibility of the user of this standard to establish appro-priate safety and health practices and determine the applica-bility of regulatory limitations prior to use.2.Referenced Documents2.1ASTM Standards:2D97Test Method for Pour Point of Petroleum Products D323Test Method for Vapor Pressure of Petroleum Prod-ucts(Reid Method)D1250Guide for Use of the Petroleum Measurement TablesD2500Test Method for Cloud Point of Petroleum OilsD3117Test Method for Wax Appearance Point of Distillate FuelsD4057Practice for Manual Sampling of Petroleum and Petroleum Products(API MPMS Chapter8.1)D4177Practice for Automatic Sampling of Petroleum and Petroleum Products(API MPMS Chapter8.2)D5854Practice for Mixing and Handling of Liquid Samples of Petroleum and Petroleum Products(API MPMS Chapter8.3)E1Specification for ASTM Liquid-in-Glass Thermometers E100Specification for ASTM Hydrometers2.2API Standards:3MPMS Chapter8.1Manual Sampling of Petroleum and Petroleum Products(ASTM Practice D4057)MPMS Chapter8.2Automatic Sampling of Petroleum and Petroleum Products(ASTM Practice D4177)1This test method is under the jurisdiction of ASTM Committee D02on Petroleum Products and Lubricants and the API Committee on Petroleum Measure-ment,and is the direct responsibility of D02.02/COMQ,the joint ASTM-API Committee on Static Petroleum Measurement.Current edition approved Nov.1,2005.Published December2005.Originally approved st previous edition approved in1999as D1298–99e2.2For referenced ASTM standards,visit the ASTM website,,or contact ASTM Customer Service at service@.For Annual Book of ASTM Standards volume information,refer to the standard’s Document Summary page on the ASTM website.3Published as Manual of Petroleum Measurement Standards.Available from the American Petroleum Institute(API),1220L St.,NW,Washington,DC20005.Copyright©ASTM International,100Barr Harbor Drive,PO Box C700,West Conshohocken,PA19428-2959,United States.MPMS Chapter8.3Mixing and Handling of Liquid Samples of Petroleum and Petroleum Products(ASTM Practice D5854)2.3Institute of Petroleum Standards:4IP389Determination of wax appearance temperature (WAT)of middle distillate fuels by differential thermal analysis(DTA)or differential scanning calorimetry(DSC) IP Standard Methods Book,Appendix A,Specifications–IP Standard Thermometers2.4ISO Standards:5ISO649-1Laboratory glassware–Density hydrometers for general purpose–Part1:Specification3.Terminology3.1Definitions of Terms Specific to This Standard:3.1.1API gravity,n—a special function of relative density (specific gravity)60/60°F,represented by:°API5141.5/~sp gr60/60°F!2131.5(1) 3.1.1.1Discussion—No statement of reference temperature is required,as60°F is included in the definition.3.1.2cloud point,n—temperature at which a cloud of wax crystalsfirst appears in a liquid when it is cooled under specific conditions.3.1.3density,n—the mass of liquid per unit volume at15°C and101.325kPa with the standard unit of measurement being kilograms per cubic metre.3.1.3.1Discussion—Other reference temperatures,such as 20°C,may be used for some products or in some locations. Less preferred units of measurement(for example,kg/L or g/mL)are still in use.3.1.4observed values,n—values observed at temperatures other than the specified reference temperature.These values are only hydrometer readings and not density,relative density (specific gravity),or API gravity at that other temperature. 3.1.5pour point,n—lowest temperature at which a test portion of crude petroleum or petroleum product will continue toflow when it is cooled under specified conditions.3.1.6relative density(specific gravity),n—the ratio of the mass of a given volume of liquid at a specific temperature to the mass of an equal volume of pure water at the same or different temperature.Both reference temperatures shall be explicitly stated.3.1.6.1Discussion—Common reference temperatures in-clude60/60°F,20/20°C,20/4°C.The historic deprecated term specific gravity may still be found.3.1.7wax appearance temperature(WAT),n—temperature at which waxy solids form when a crude petroleum or petroleum product is cooled under specified conditions.4.Summary of Test Method4.1The sample is brought to a specified temperature and a test portion is transferred to a hydrometer cylinder that has been brought to approximately the same temperature.The appropriate hydrometer,also at a similar temperature,is lowered into the test portion and allowed to settle.After temperature equilibrium has been reached,the hydrometer scale is read,and the temperature of the test portion is taken. The observed hydrometer reading is reduced to the reference temperature by means of the Petroleum Measurement Tables.If necessary,the hydrometer cylinder and its contents are placed in a constant temperature bath to avoid excessive temperature variation during the test.5.Significance and Use5.1Accurate determination of the density,relative density (specific gravity),or API gravity of petroleum and its products is necessary for the conversion of measured volumes to volumes or masses,or both,at the standard reference tempera-tures during custody transfer.5.2This test method is most suitable for determining the density,relative density(specific gravity),or API gravity of low viscosity transparent liquids.This test method can also be used for viscous liquids by allowing sufficient time for the hydrometer to reach equilibrium,and for opaque liquids by employing a suitable meniscus correction.5.3When used in connection with bulk oil measurements, volume correction errors are minimized by observing the hydrometer reading at a temperature close to that of the bulk oil temperature.5.4Density,relative density(specific gravity),or API grav-ity is a factor governing the quality and pricing of crude petroleum.However,this property of petroleum is an uncertain indication of its quality unless correlated with other properties.5.5Density is an important quality indicator for automotive, aviation and marine fuels,where it affects storage,handling and combustion.6.Apparatus6.1Hydrometers,of glass,graduated in units of density, relative density,or API gravity as required,conforming to Specification E100or ISO649-1,and the requirements given in Table1.6.1.1The user should ascertain that the instruments used for this test conform to the requirements set out above with respect to materials,dimensions,and scale errors.In cases where the instrument is provided with a calibration certificate issued by a recognized standardizing body,the instrument is classed as certified and the appropriate corrections listed shall be applied4Available from Energy Institute,61New Cavendish St.,London,W1M8AR, UK.5Available from American National Standards Institute(ANSI),25W.43rd St., 4th Floor,New York,NY10036.TABLE1Recommended HydrometersUnits Range Scale A MeniscusTotalEachUnitInterval A Error A CorrectionDensity,kg/m3at15°C600-1100600-1100600-11002050500.20.51.060.260.360.6+0.3+0.7+1.4 Relative density(specificgravity)60/60°F0.600-1.1000.600-1.1000.600-1.1000.0200.0500.0500.00020.00050.00160.000260.000360.0006+0.0003+0.0007+0.0014 Relative density(specificgravity),60/60°F0.650-1.1000.0500.000560.0005API−1-+101120.160.1A Interval and Error relate toScale.to the observed readings.Instruments that satisfy the require-ments of this test method,but are not provided with a recognized calibration certificate,are classed as uncertified.6.2Thermometers ,having range,graduation intervals and maximum permitted scale error shown in Table 2and conform-ing to Specification E 1or IP Appendix A .6.2.1Alternate measuring devices or systems may be used,provided that the total uncertainty of the calibrated system is no greater than when using liquid-in-glass thermometers.6.3Hydrometer Cylinder ,clear glass,plastic (see 6.3.1),or metal.The inside diameter of the cylinder shall be at least 25mm greater than the outside diameter of the hydrometer and the height shall be such that the appropriate hydrometer floats in the test portion with at least 25mm clearance between the bottom of the hydrometer and the bottom of the cylinder.6.3.1Hydrometer cylinders constructed of plastic materials shall be resistant to discoloration or attack by oil samples and shall not affect the material being tested.They shall not become opaque under prolonged exposure to sunlight.6.4Constant-Temperature Bath ,if required,of dimensions such that it can accommodate the hydrometer cylinder with the test portion fully immersed below the test portion liquid surface,and a temperature control system capable of maintain-ing the bath temperature within 0.25°C of the test temperature throughout the duration of the test.6.5Stirring Rod ,optional,of glass or plastic,approximately 400mm in length.7.Sampling7.1Unless otherwise specified,samples of non-volatile petroleum and petroleum products shall be taken by the procedures described in Practices D 4057(API MPMS Chapter 8.1)and D 4177(API MPMS Chapter 8.2).7.2Samples of volatile crude petroleum or petroleum prod-ucts are preferably taken by Practice D 4177(API MPMS Chapter 8.2),using a variable volume (floating piston)sample receiver to minimize any loss of light components which may affect the accuracy of the density measurement.In the absence of this facility,extreme care shall be taken to minimize these losses,including the transfer of the sample to a chilled container immediately after sampling.7.3Sample Mixing —May be necessary to obtain a test portion representative of the bulk sample to be tested,but precautions shall be taken to maintain the integrity of the sample during this operation.Mixing of volatile crude petro-leum or petroleum products containing water or sediments,or both,or the heating of waxy volatile crude petroleum or petroleum products may result in the loss of light components.The following sections (7.3.1to 7.3.4)will give some guidance on sample integrity maintenance.7.3.1Volatile Crude Petroleum and Petroleum Products Having an RVP Greater than 50kPa —Mix the sample in its original closed container in order to minimize the loss of light components.N OTE 1—Mixing volatile samples in open containers will lead to loss of light components and consequently affect the value of the density obtained.7.3.2Waxy Crude Petroleum —If the petroleum has a pour point above 10°C,or a cloud point or WAT above 15°C,warm the sample to 9°C above the pour point,or 3°C above the cloud point or WAT,prior to mixing.Whenever possible,mix the sample in its original closed container in order to minimize the loss of light components.7.3.3Waxy Distillate —Warm the sample to 3°C above its cloud point or WAT prior to mixing.7.3.4Residual Fuel Oils —Heat the sample to the test temperature prior to mixing (see 8.1.1and Note 4).7.4Additional information on the mixing and handling of liquid samples will be found in Practice D 5854(API MPMS Chapter 8.3).8.Procedure8.1Temperature of Test :8.1.1Bring the sample to the test temperature which shall be such that the sample is sufficiently fluid but not so high as to cause the loss of light components,nor so low as to result in the appearance of wax in the test portion.N OTE 2—The density,relative density or API gravity determined by the hydrometer is most accurate at or near the reference temperature.N OTE 3—The volume and density,the relative density,and the API corrections in the Petroleum Measurement Tables are based on the average expansions of a number of typical materials.Since the same coefficients were used in compiling each set of tables,corrections made over the same temperature interval minimize errors arising from possible differences between the coefficient of the material under test and the standard coefficients.This effect becomes more important as temperatures diverge from the reference temperature.N OTE 4—The hydrometer reading is obtained at a temperature appro-priate to the physico-chemical characteristics of the material under test.This temperature is preferably close to the reference temperature,or when the value is used in conjunction with bulk oil measurements,within 3°C of the bulk temperature (see 5.3).8.1.2For crude petroleum,bring the sample close to the reference temperature or,if wax is present,to 9°C above its pour point or 3°C above its cloud point or WAT,whichever is higher.N OTE 5—For crude petroleum an indication of the WAT can be found using IP 389,with the modification of using 50µL 65µL of sample.The precision of WAT for crude petroleum using this technique has not been determined.9.Apparatus Verification or Certification9.1Hydrometers and thermometers shall be verified in accordance with the procedures in Annex A1.10.Procedure10.1Bring the hydrometer cylinder and thermometer to within approximately 5°C of the test temperature.10.2Transfer the sample to the clean,temperature-stabilized hydrometer cylinder without splashing,to avoid theTABLE 2Recommended ThermometersScale Range Graduation IntervalScale Error °C −1-+380.160.1°C −20-+1020.260.15°F−5-+2150.560.25formation of air bubbles,and minimize evaporation of the lower boiling constituents of more volatile samples. (Warning—Extremelyflammable.Vapors may causeflash fire!)10.3Transfer highly volatile samples by siphoning or water displacement.(Warning—Siphoning by mouth could result in ingestion of sample!)10.3.1Samples containing alcohol or other water-soluble materials should be placed into the cylinder by siphoning. 10.4Remove any air bubbles formed after they have col-lected on the surface of the test portion,by touching them witha piece of cleanfilter paper before inserting the hydrometer.10.5Place the cylinder containing the test portion in a vertical position in a location free from air currents and where the temperature of the surrounding medium does not change more than2°C during the time taken to complete the test. When the temperature of the test portion differs by more than 2°C from ambient,use a constant temperature bath to maintain an even temperature throughout the test duration.10.6Insert the appropriate thermometer or temperature measurement device and stir the test portion with a stirring rod, using a combination of vertical and rotational motions to ensure uniform temperature and density throughout the hy-drometer cylinder.Record the temperature of the sample to the nearest0.1°C and remove the thermometer/temperature mea-suring device and stirring rod from the hydrometer cylinder. N OTE6—If a liquid-in-glass thermometer is used,this is commonly used as the stirring rod.10.7Lower the appropriate hydrometer into the liquid and release when in a position of equilibrium,taking care to avoid wetting the stem above the level at which itfloats freely.For low viscosity transparent or translucent liquids observe the meniscus shape when the hydrometer is pressed below the point of equilibrium about1to2mm and allowed to return to equilibrium.If the meniscus changes,clean the hydrometer stem and repeat until the meniscus shape remains constant.10.8For opaque viscous liquids,allow the hydrometer to settle slowly into the liquid.10.9For low viscosity transparent or translucent liquids depress the hydrometer about two scale divisions into the liquid,and then release it,imparting a slight spin to the hydrometer on release to assist in bringing it to restfloating freely from the walls of the hydrometer cylinder.Ensure that the remainder of the hydrometer stem,which is above the liquid level,is not wetted as liquid on the stem affects the reading obtained.10.10Allow sufficient time for the hydrometer to come to rest,and for all air bubbles to come to the surface.Remove any air bubbles before taking a reading(see10.4).10.11If the hydrometer cylinder is made of plastic,dissi-pate any static charges by wiping the outside with a damp cloth.(Warning—Static charges often build up on plastic cylinders and may prevent the hydrometer fromfloating freely.)10.12When the hydrometer has come to restfloating freely away from the walls of the cylinder,read the hydrometer scale reading to the nearest one-fifth of a full scale division in accordance with10.12.1or10.12.2.10.12.1For transparent liquids,record the hydrometer read-ing as the point on the hydrometer scale at which the principal surface of the liquid cuts the scale by placing the eye slightly below the level of the liquid and slowly raising it until the surface,first seen as a distorted ellipse,appears to become a straight line cutting the hydrometer scale(see Fig.1).10.12.2For opaque liquids record the hydrometer reading at the point on the hydrometer scale to which the sample rises,by observing with the eye slightly above the plane of the surface of the liquid(see Fig.2).N OTE7—When testing opaque liquids using a metal hydrometer cylinder,accurate readings of the hydrometer scale can only be ensured if the liquid surface is within5mm of the top of the cylinder.10.13Immediately after recording the hydrometer scale reading,carefully lift the hydrometer out of the liquid,insert the thermometer or temperature measurement device and stir the test portion vertically with the stirring rod.Record the temperature of the test portion to the nearest0.1°C.If this temperature differs from the previous reading(10.6)by more than0.5°C,repeat the hydrometer observations and thermom-eter observations until the temperature becomes stable within 0.5°C.If a stable temperature cannot be obtained,place the hydrometer cylinder in a constant temperature bath and repeat the procedure from10.5.FIG.1Hydrometer Scale Reading for TransparentLiquids10.14If the test temperature is higher than 38°C,allow all hydrometers of the lead shot-in-wax type to drain and cool in a vertical position.11.Calculation11.1Apply any relevant thermometer corrections to the temperature reading observed in 10.6and 10.13and record the average of those two temperatures to the nearest 0.1°C.11.2For opaque samples,apply the relevant meniscus correction given in Table 1to the observed hydrometer reading (10.12.2)as hydrometers are calibrated to be read at the principal surface of the liquid.N OTE 8—The meniscus correction for a particular hydrometer in use is determined by observing the maximum height above the principal surface of the liquid to which liquid rises on the hydrometer scale when the hydrometer in question is immersed in a transparent liquid having a surface tension similar to that of the sample under test.For hydrometers specified in this test method,the corrections in Table 1are approximate.11.3Apply any hydrometer correction to the observed reading and record the corrected hydrometer scale reading to the nearest 0.1kg/m 3in density,0.0001g/mL,kg/L or relative density,or 0.1°API.11.4If the hydrometer has been calibrated at a temperature other than the reference temperature,use the equation below to correct the hydrometer scale reading:r r 5r t1–[23310–6~t –r !–2310–8~t –r !2#(2)where:r r =hydrometer reading at the reference temperature,r °C,andr t =hydrometer reading on the hydrometer scale whosereference temperature is t °C.11.5Convert the corrected hydrometer scale reading to density,relative density,or API gravity using the appropriate parts of the Petroleum Measurement Tables referenced in Guide D 1250according to the nature of the materials under test.Table 3gives some examples of relevant table numbers in the Petroleum Measurement Tables.11.5.1The strictly correct procedure for the conversion is to use the computer implementation procedures contained in the Petroleum Measurement Tables and not the printed tables.If the printed tables are used,ensure that all errata discovered since original publication have been included in the version used.The tables include corrections for soda-lime glass expan-sion and contraction of the hydrometer over the temperature range,and thus the observed hydrometer reading is added directly after correction (11.2-11.4)as necessary.11.5.2To convert densities expressed in kg/m 3to densities expressed in g/mL or kg/L,divide by 103.11.5.3To convert hydrometer readings from one unit to another,Tables 51(density at 15°C),21(relative density at 60/60°F),or 3(API gravity),referenced in Guide D 1250,are appropriate.12.Report12.1Report the final value as density,in kilograms per cubic metre,at the reference temperature,to the nearest 0.1kg/m 3.12.2Report the final value as density,in kilograms per litre or grams per millilitre at the reference temperature,to the nearest 0.0001.12.3Report the final value as relative density,with no dimensions,at the two reference temperatures,to the nearest 0.0001.12.4Report the final value as API gravity to the nearest 0.1°API.13.Precision and Bias13.1Precision —The precision of the method as determined by statistical examination of interlaboratory results is as follows:13.1.1Repeatability —The difference between two test re-sults,obtained by the same operator with the same apparatus under constant operating conditions on identical test material,would in the long run,in the normal and correct operation of the test method,exceed the values in Table 4only in 1case in20.FIG.2Hydrometer Scale Reading for Opaque FluidsTABLE 3Example PMT Table NumbersMaterialDensity at 15°C kg/m 3Density at 20°C kg/m 3Relative Density at 60/60°F°APICrude petroleum 53A 59A 23A 5A Petroleum products 53B 59B 23B 5B Lubricating oils53D59D–5D13.1.2Reproducibility —The difference between two single and independent results obtained by different operators work-ing in different laboratories on identical test material would,in the long run,in the normal and correct operation of the test method,exceed the following values only in 1case in 20.13.2Bias —Bias for this test method has not been deter-mined.However,there should be no bias from absolute measurements,if the calibration of the hydrometer and the thermometer is traceable to International Standards,such as supplied by the National Institute of Standards and Technology.14.Keywords14.1API gravity;crude petroleum;density;hydrometer;Petroleum Measurement Tables;petroleum products;relative density;specific gravityANNEX(Mandatory Information)A1.APPARATUSA1.1Apparatus Verification and CertificationA1.1.1Hydrometers ,shall either be certified or verified.Verification shall be either by comparison with a certified hydrometer (see 6.1.1)or by the use of a certified reference material (CRM)specific to the reference temperature used.A1.1.1.1The hydrometer scale shall be correctly located within the hydrometer stem by reference to the datum mark.If the scale has moved,reject the hydrometer.A1.1.2Thermometers ,shall be verified at intervals of no more than six months for conformance with specifications.Either comparison with a referenced temperature measurement system traceable to an international standard,or a determina-tion of ice point,is suitable.ASTM International takes no position respecting the validity of any patent rights asserted in connection with any item mentioned in this ers of this standard are expressly advised that determination of the validity of any such patent rights,and the risk of infringement of such rights,are entirely their own responsibility.This standard is subject to revision at any time by the responsible technical committee and must be reviewed every five years and if not revised,either reapproved or withdrawn.Your comments are invited either for revision of this standard or for additional standards and should be addressed to ASTM International Headquarters.Your comments will receive careful consideration at a meeting of the responsible technical committee,which you may attend.If you feel that your comments have not received a fair hearing you should make your views known to the ASTM Committee on Standards,at the address shown below.This standard is copyrighted by ASTM International,100Barr Harbor Drive,PO Box C700,West Conshohocken,PA 19428-2959,United States.Individual reprints (single or multiple copies)of this standard may be obtained by contacting ASTM at the above address or at 610-832-9585(phone),610-832-9555(fax),or service@ (e-mail);or through the ASTM website ().TABLE 4Precision ValuesProduct:Transparent Low-viscosity LiquidsParameter Temperature Range,°C (°F)Units Repeat-ability Repro-ducibility Density –2to 24.5(29to 76)kg/m 3kg/L or g/mL 0.50.0005 1.20.0012Relative Density –2to 24.5(29to 76)NONE0.00050.0012API Gravity(42to 78)°API0.10.3Product:Opaque LiquidsParameter Temperature Range,°C (°F)Units Repeat-ability Repro-ducibility Density –2to 24.5(29to 76)kg/m 3kg/L or g/mL 0.60.0006 1.50.0015Relative Density –2to 24.5(29to 76)NONE0.00060.0015API Gravity(42to 78)°API0.20.5。
2024中石油工作总结范文(二篇)
2024中石油工作总结范文标题：____年中石油工作总结摘要：____年，中石油公司在国内外油气勘探开发领域取得了显著成绩。
公司坚持创新发展，加强自主研发能力，推动技术进步和管理创新。
同时，公司高度重视社会责任，注重可持续发展，积极推进环境保护和安全生产。
本文通过详细分析，系统总结了____年中石油在勘探开发、技术创新、经营管理和社会责任履行等方面的工作。
第一部分：勘探开发工作1.国内勘探开发____年，中石油在国内油气勘探开发方面取得重大突破。
公司加大了勘探投入，深入开展深水勘探工作，发现了多个重要油气田。
同时，公司通过技术改造和优化开发方案，提高了储量和产能，实现了资源的高效利用。
此外，公司还积极推进页岩气开发，实现了产量的快速增长。
2.海外勘探开发中石油在____年海外勘探开发方面取得了显著进展。
公司积极拓展海外资源合作，加强与国际能源公司的合作，稳步推进境外项目。
公司在南美、非洲等地发现了多个大型油气田，为公司的全球资源布局做出了重要贡献。
第二部分：技术创新工作1.自主研发能力提升中石油在____年加强了自主研发能力建设。
公司注重创新驱动，加大研发投入，加强技术攻关和创新团队建设。
通过自主研发，公司成功开发出多项关键技术，提高了勘探和开发效率，降低了成本。
2.数字化管理推进为了提高工作效率和管理水平，中石油在____年大力推进数字化管理。
公司加大智能化设备的应用，推动信息系统建设，实现了数据的统一管理和监控。
这样不只提高了生产效率，还加强了工作安全和环境保护的管理。
第三部分：经营管理工作1.财务管理中石油在____年经营管理方面加强了财务管理。
公司积极控制成本，优化资金结构，提高资产负债比率和信用等级。
同时，公司注重财务风险管理，建立了健全的财务制度和内部控制机制。
2.人力资源管理为了适应公司发展需求，中石油在____年加强了人力资源管理。
公司重视人才培养和引进，建立了完善的职业发展体系和激励机制。
资产评估-国外评估准则
资产评估-国外评估准则引言概述：资产评估是指对各类资产进行估值和评估的过程，是企业决策和财务报告的重要依据。
不同国家和地区在资产评估方面往往采用不同的准则和方法。
本文将介绍国外资产评估的一些常用准则和方法。
一、国外资产评估准则的概述1.1 国际财务报告准则（IFRS）IFRS是国际上广泛应用的财务报告准则，对资产评估提供了详细的规定。
其中，IAS 16《固定资产》规定了固定资产的初始计量、后续计量和减值测试等方面的要求。
IAS 36《资产减值》则规定了资产减值测试的方法和程序。
1.2 美国公认会计准则（US GAAP）US GAAP是美国广泛应用的会计准则，对资产评估也提供了相应的规定。
FASB 141《企业合并与收购》规定了企业合并时的资产评估方法，FASB 157《公允价值计量》则规定了公允价值的确定方法。
1.3 国际评估准则委员会（IVSC）IVSC是国际评估行业的权威组织，发布了一系列的评估准则。
其中，IVS 2022《国际评估准则》规定了评估师在资产评估过程中应遵循的原则和方法。
二、资产评估的方法和技术2.1 市场比较法市场比较法是一种常用的资产评估方法，通过比较市场上类似资产的交易价格，确定被评估资产的价值。
这种方法适合于有大量交易数据和市场活跃的资产，如房地产和股票等。
2.2 收益法收益法是一种基于资产未来现金流量预测的评估方法。
它通过估计资产的未来现金流量，并将其折现到现值，计算出资产的价值。
这种方法适合于对收益稳定、现金流量可预测的资产进行评估。
2.3 成本法成本法是一种基于资产重建成本的评估方法。
它通过估计资产的重建成本，并考虑到资产的折旧和使用寿命等因素，计算出资产的价值。
这种方法适合于对固定资产等重建成本可确定的资产进行评估。
三、资产评估的挑战和问题3.1 信息不对称性资产评估过程中，评估师和被评估方之间往往存在信息不对称的问题。
被评估方可能故意隐瞒或者误导评估师，导致评估结果不许确。
IAS16
目的本号准则的目的是规定不动产、厂房和设备的会计处理。
不动产、厂房和设备的会计的基本问题是资产确认的时间、其帐面金额的确定、与它们有关的需确认的折旧费用，以及对帐面金额的其他损耗的确定和会计处理。
Objective1 The objective of this Standard is to prescribe the accounting treatment for property, plant and equipment so that users of the financial statements can discern information about an entity‘s investment in its property, plant and equipment and the changes in such investment. The principal issues in accounting for property, plant and equipment are the recognition of the assets, the determination of their carrying amounts and the depreciation charges and impairment losses to be recognised in relation to them.范围Scope本号准则适用于对不动产、厂房和设备的会计处理，除非有另外的国际会计准则，要求或允许采用不同的会计处理方法。
2 This Standard shall be applied in accounting for property, plant and equipment except when another Standard requires or permits a different accounting treatment.本号准则不适用于：3 This Standard does not apply to:(a) property, plant and equipment classified as held for sale in accordance with IFRS5 Non-current Assets Held for Sale and Discontinued Operations;(b) biological assets related to agricultural activity (see IAS 41 Agriculture);(c) the recognition and measurement of exploration and evaluation assets (see IFRS 6 Exploration for and Evaluation of Mineral Resources); or矿产权，矿产、石油、天然气和类似的非再生性资源的勘探和开采。
中石油职业智力测试题目(3篇)
第1篇一、选择题（每题2分，共20分）1. 下列哪项不属于石油勘探开发过程中的关键环节？A. 地质勘探B. 钻井作业C. 油气集输D. 石油化工2. 以下哪个单位是石油工程测量中最常用的坐标系统？A. 经纬度坐标系统B. 高斯-克吕格坐标系统C. 地球坐标系D. 投影坐标系3. 在石油开采过程中，下列哪种方法可以有效提高采收率？A. 热力驱B. 化学驱C. 物理驱D. 以上都是4. 下列哪种设备在石油钻井过程中用于提升钻具？A. 钻机B. 钻杆C. 钻头D. 钻台5. 以下哪个国家是世界上最大的石油生产国？B. 美国C. 沙特阿拉伯D. 中国6. 石油工程中，下列哪个参数表示地层压力？A. 地层孔隙压力B. 地层水压力C. 地层压力D. 地下水压力7. 以下哪种方法可以用于油气藏的动态监测？A. 地震勘探B. 地质测井C. 地球物理勘探D. 以上都是8. 在石油工程中，下列哪种设备用于将油气输送到地面？A. 油罐车B. 集输管道C. 油气处理装置D. 以上都是9. 以下哪个单位是石油工程中最常用的体积单位？A. 立方米B. 立方厘米C. 升10. 在石油工程中，下列哪种设备用于提高原油的流动性？A. 真空泵B. 加热炉C. 搅拌器D. 以上都是二、判断题（每题2分，共20分）1. 石油工程中，地震勘探是一种常用的勘探方法。
（）2. 钻井作业中，钻杆是用来传递钻头旋转动力的。
（）3. 油气集输过程中，油气处理装置的主要作用是分离油、气、水。
（）4. 石油化工是指将原油直接转化为各种化工产品的过程。
（）5. 地质测井是一种直接获取地层信息的方法。
（）6. 石油工程中，地球物理勘探主要用于油气藏的动态监测。
（）7. 油气田开发过程中，提高采收率的主要方法是物理驱。
（）8. 钻头是石油钻井过程中最重要的部件。
（）9. 石油工程中，集输管道的直径越大，输油效率越高。
（）10. 石油工程中，钻井液的主要作用是冷却钻头和携带岩屑。
IAS 16 国际会计准则16号 固定资产PPE
2013IAS 16 Property, Plant and Equipmentas issued at 1 January 2013. Includes IFRSs with an effective date after 1 January 2013 but not the IFRSs they will replace.This extract has been prepared by IFRS Foundation staff and has not been approved by the IASB. For the requirements reference must be made to International Financial Reporting Standards.The objective of this Standard is to prescribe the accounting treatment for property, plant and equipment so that users of the financial statements can discern information about an entity’s investment in its property, plant and equipment and the changes in such investment. The principal issues in accounting for property, plant and equipment are the recognition of the assets, the determination of their carrying amounts and the depreciation charges and impairment losses to be recognised in relation to them.Property, plant and equipment are tangible items that:(a)are held for use in the production or supply of goods or services, for rental to others, or for administrativepurposes; and(b)are expected to be used during more than one period.The cost of an item of property, plant and equipment shall be recognised as an asset if, and only if:(a)it is probable that future economic benefits associated with the item will flow to the entity; and(b)the cost of the item can be measured reliably.Measurement at recognition: An item of property, plant and equipment that qualifies for recognition as an asset shall be measured at its cost. The cost of an item of property, plant and equipment is the cash price equivalent at the recognition date. If payment is deferred beyond normal credit terms, the difference between the cash price equivalent and the total payment is recognised as interest over the period of credit unless such interest is capitalised in accordance with IAS 23.The cost of an item of property, plant and equipment comprises:(a)its purchase price, including import duties and non-refundable purchase taxes, after deducting tradediscounts and rebates.(b)any costs directly attributable to bringing the asset to the location and condition necessary for it to becapable of operating in the manner intended by management.(c)the initial estimate of the costs of dismantling and removing the item and restoring the site on which it islocated, the obligation for which an entity incurs either when the item is acquired or as a consequence of having used the item during a particular period for purposes other than to produce inventories during that period.Measurement after recognition: An entity shall choose either the cost model or the revaluation model as its accounting policy and shall apply that policy to an entire class of property, plant and equipment.Cost model: After recognition as an asset, an item of property, plant and equipment shall be carried at its cost less any accumulated depreciation and any accumulated impairment losses.Revaluation model: After recognition as an asset, an item of property, plant and equipment whose fair value can be measured reliably shall be carried at a revalued amount, being its fair value at the date of the revaluation less any subsequent accumulated depreciation and subsequent accumulated impairment losses. Revaluations shall be made with sufficient regularity to ensure that the carrying amount does not differ materially from that which would be determined using fair value at the end of the reporting period.If an asset’s carrying amount is increased as a result of a revaluation,the increase shall be recognised in other comprehensive income and accumulated in equity under the heading of revaluation surplus. However, the increase shall be recognised in profit or loss to the extent that it reverses a revaluation decrease of the same asset previously recognised in profit or loss. If an asset’s carrying amount is decreased as a result of a revaluation,the decrease shall be recognised in profit or loss. However, the decrease shall be recognised in other comprehensive income to the extent of any credit balance existing in the revaluation surplus in respect of that asset.Depreciation is the systematic allocation of the depreciable amount of an asset over its useful life. Depreciable amount is the cost of an asset, or other amount substituted for cost, less its residual value. Each part of an item of property, plant and equipment with a cost that is significant in relation to the total cost of the item shall be depreciated separately. The depreciation charge for each period shall be recognised in profit or loss unless it is included in the carrying amount of another asset. The depreciation method used shall reflect the pattern in which the asset’s future economic benefits are expected to be consumed by the entity.The residual value of an asset is the estimated amount that an entity would currently obtain from disposal of the asset, after deducting the estimated costs of disposal, if the asset were already of the age and in the condition expected at the end of its useful life.To determine whether an item of property, plant and equipment is impaired, an entity applies IAS 36 Impairment of Assets.The carrying amount of an item of property, plant and equipment shall be derecognised:(a)on disposal; or(b)when no future economic benefits are expected from its use or disposal.。
油气储量资产价值评估方法
油气储量资产价值评估方法蒋南倩【摘要】油气储量能够体现出一个石油公司的价值,同时也是其最为核心的资产.以国际通用标准来评估油气储量是衡量一个石油公司价值和成长性的重要手段.本文简单介绍了油气储量的定义,总结了当前常用的油气储量价值评估方法以及各种方法的特点,并对现有的几种主要评估方法做出相应的分析评价.【期刊名称】《化工中间体》【年(卷),期】2016(000)010【总页数】2页(P137-138)【关键词】油气储量;资产评估;方法【作者】蒋南倩【作者单位】中国石化集团国际石油勘探开发有限公司北京 100029【正文语种】中文【中图分类】T油气储量，是石油工业得以生存和延续的前提，也是具有一定资本属性的一种特殊资产。
对油田的油气储量进行科学准确的评估，能够有效保障储量交易市场规范运作，也是加强油气储量资产内部管理的重要手段，同时也在一定程度上减少了资源浪费的状况。
对油气储量的评估不仅包括油气储量数量的估算，还包括储量价值量的评估。
做好油气储量价值评估工作是我国加入国际油气储量市场交易的前提，也是实现我国油气开采企业科学决策和资源高效利用的必要条件。
(1)油气储量国外对油气储量的定义为：储量是指估算的原油、凝析油、天然气和其伴生物质，在目前经济条件下，采用现有技术，根据现行的政府法规，从一个指定的日期算起，它们从己知油气聚集体中，预计可以商业性采出的数量。
由此可知，油气储量不只是一种较为重要的资产，还是一种价值量较高的商品。
国内对油气储量的定义为：资源量——在一定特定时间，估计地层中已发现和待发现的油气聚集的总量。
储量——资源量中己发现的部分。
通常描述为油气储量是指在地层原始条件下，具有产油气能力的储层中油气的总量。
(2)油气储量资产的特点油气储量资产具有一定的特殊性、不确定性，以下总结出几点油气资产的主要特点：①油气储量数量具有长期性与不确定性。
从油气储量正式确认到储量资源枯竭会有较长的时间跨度，因此，油气储量在很长一段时间内都能给油气企业带来相当可观的经济利益，它为企业的持续经营发展带来的作用至关重要。
中国石化业务分类知识
A6.4技术质量管理
A6.2.1炼油工程技术
A6.3.1生产经营计划 A6.3.2工程咨询
A6.4.1 技术管理
A6.4.2 质量管理
A6.2.2化工工程技术 A6.1.3 境外市场 A6.1.4 客户管理 A6.1.5 投标报价 A6.1.6 合同管理
A6.3.3 工程设计 A6.4.3标准规范 A6.3.4工程采购 A6.4.4 资质管理 A6.3.5 装备制造 A6.3.6 工程施工 A6.3.7 开车服务
A2.1.5 供应商/代理商绩 效管理
A2.5.2 罐区、库存作业
7
业务分类-A3化工生产与销售
A3.1原料供应与运输 A3.1.1原料采购计划 A3.1.2原料采购合同 A3.1.3原料运输 A3.2生产运行 A3.2.1生产计划 A3.2.2生产指挥/生产 调度 A3.3化工品采购 A3.3.1化工品采购管理 A3.3.2化工品进口管理 A3.3.3供应商管理 A3.4化工品物流 A3.4.1物流计划 A3.4.2运输管理 A3.4.3仓储管理 A3.5化工品销售 A3.5.1市场分析 A3.5.2营销策略 A3.5.3销售计划 A3.5.4价格管理 A3.5.5保供管理 A3.5.6销售过程管理 A3.5.7化工品出口管理 A3.5.8客户管理 A3.5.9客户服务 A3.5.10网点代表处管理
A6.2.3工厂技术
A6.1.7 售后服务
A6.3.8 EPC总承包 A6.3.9 项目管理服务
11
业务分类-A7原油和产品贸易
A7.1 原油战略供应管理 A7.1.1全球供应网络 管理与优化 A7.1.2供应商准入管 理 A7.1.3长期原油供应 协议管理 A7.1.4供应商绩效管 理 A7.2 原油和产品采购 A7.2.1 原油采购计 划 A7.2.2 产品采购计 划 A7.2.3合同和代理协 议管理 A7.2.4价格管理 A7.2.5信用证管理 A7.2.6 进口、通关和 检验 A7.2.7 质量检验 A7.3.5 仓储管理 A7.3.6 原油和产品 接卸 A7.3 运输、仓储 A7.3.1 物流和运输 计划 A7.3.2 承运商管理 A7.3.3 运输合同管 理 A7.3.4 运输管理 A7.4 原油和产品销售 A7.4.1 原油销售计 划 A7.4.2 产品销售计 划 A7.4.3 客户管理 A7.4.4 合同和代理 协议管理 A7.4.5 价格管理 A7.4.6信用证管理 A7.4.7 出口、通关 和检验 A7.4.8 质量检验 A7.5贸易风险管理
28企业会计准则讲解2008第二十八章石油天然气开采
第二十八章石油天然气开采第一节石油天然气开采概述石油天然气行业是为国民经济提供重要能源的矿产采掘行业，生产对象是不可再生的油气资源，生产活动所依赖的主要是埋藏于地下的油气储量，其生产过程包括矿区权益的获取、油气勘探、油气开发和油气生产等内容。
由于石油天然气特殊的生产过程，其生产经营活动具有高投入、高风险、投资回收期长、油气储量发现成本与发现储量的价值之间不存在密切相关关系等特点。
相应地，石油天然气会计核算的内容与模式等也具有一些独有的特点。
石油天然气开采(以下简称”油气开采”)的会计核算是以矿区为基础的。
矿区是指企业开展油气开采活动所处的区域，具有相同的油藏地质构造或储层条件，并具有独立的压力系统和独立的集输系统，可作为独立的开发单元。
矿区是计提折耗、进行减值测试等活动的成本中心，是石油天然气会计中的重要概念。
矿区的划分应遵循以下原则:(1)一个油气藏可作为一个矿区；(2)若干相邻且地质构造或储层条件相同或相近的油气藏可作为一个矿区；(3)一个独立集输计量系统为一个矿区；(4)一个大的油气藏分为几个独立集输系统并分别计量的，可以分为几个矿区；(5)采用重大、新型采油技术并工业化推广的区域可作为一个矿区；(6)一般而言，划分矿区应优先考虑国家的不同，在同一地理区域内不得将分属不同国家的作业区划分在同一个矿区或矿区组内。
在油气开采活动中，与某一或某几个油气藏相关的单项资产，例如单井，能够单独产生可计量现金流量的情况极为少见。
通常情况下，特定矿区在勘探、开发和生产期间所发生的所有资本化成本都是作为一个整体来产生现金流的，因此计提折耗和减值测试均应以矿区作为成本中心。
油气资产的会计核算是石油天然气会计的重要组成部分。
从事油气开采的企业所拥有或控制的井及相关设施和矿区权益统称油气资产。
油气资产是一种递耗资产，反映了企业在油气开采活动中取得的油气储量以及利用这些储量生产原油或天然气的设施的价值。
油气开采企业通过计提折耗，将油气资产的价值随着开采工作的开展逐渐转移到所开采的产品成本中。
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海外油气资产评估流程（勘探类）
注：勘探项目的评估重点是区域石油地质情况研究和有利圈闭的识别
1. 海外油气项目评估流程
第一步：快速筛选，一般根据具体资料情况1～2周完成筛选
第二步：技术经济评估——根据资料收集情况相应的评估工作量会不同，重点进
行构造的解释和描述、分析有利勘探目标、估算资源量，时间一般为几周到几个
月不等。
2. 技术评价体系&经济评价体系
3. 数据收集情况简述
描述资料收集及梳理情况——及说明将要进行的评估工作的资料基础。
资料收集清单样例如下：
资料类别 收集情况
地震数据体、导航数据
①地质及地震综合研究报告
②构造解释
③测井曲线\分层数据
④岩心分析资料
⑤地层流体分析化验资料
⑥其他：钻井、录井报告
⑦历史试油试采数据
4 技术评估
4.1 项目简况
包括地理位置（盆地）、所属国家、工区面积、合同类型、合同期限、股权构成、作业
者归属、义务工作量等等
4.2 勘探开发简史
项目勘探开发历史、已经完成的勘探开发工作量、目前的现状
4.3 地质特征
4.3.1 区域石油地质
盆地或区域的生储盖组合描述，简单描述成藏模式等。目标区所处
的具体的位置和生储盖组合情况（如是否是有利位置）。相邻已发现油田
基本情况（目的层、深度、产能等等）。
4.3.2 构造特征
构造解释和构造要素特征描述——根据资料情况，如果对方提供地
震资料，那我们有必要重新进行构造解释（相关软件LandMark R2003、
Discovery、SMT、GeoFrame）。如果对方不提供地震资料只提供解释结果，
那只能采用其结果，但要说明可能存在构造风险。
4.3.3 生油层指标（参见技术评价体系）
甘酪根类型、TOC、Ro、区域（盆地）生油层厚度分布
4.3.4 储层特征（根据相邻油田或本区已钻井情况）
a) 储层类型：岩性、储积空间、储层厚度
b) 储层物性：孔隙度、饱和度、渗透率等
4.3.5 盖层分布情况（根据相邻油田或本区已钻井情况）
4.3.6 有利目标确定及风险
a) 根据生储盖组合及区域成藏模式确定有利的勘探目标（用地
质图件标识出有利目标）
b) 根据生储盖圈运保6大要素分析勘探目标的风险性
c) 估算有利勘探目标的资源量(蒙特卡洛法)
d) 有利勘探目标风险排序
有利勘探目标排序
圈闭号 目标 层位 深度 m 生油层 风险系数 储层 盖层风险系数 圈闭 风险 系数 运移条件 保存条件 风险 系数 估算资 源量中值 (万方) 备
注
1 Pg 3000 1.0 1.0 1.0 0.5 0.5 1 0.25 1000
——参数选取、参数值、随机分布规律（正态分布。。。）
——容积法计算储量并给出：P10、P50、P90 储量值
4.4 开发调整规划方案及指标预测
油藏多方案：开采方式、开发层系、井网井距、方案工作量、开发指标预测
（含多方案和开发指标不确定性分析）
单井产能根据试油米采油指数+横向类比法确定（初产和递减率——该参数
也是不确定的），每个方案给出高中低三个预测结果。（乐观、保守、中值，便于
决策者决策参考。）
钻采工程、地面工程规划规模及工作量
5 经济评价
（第2章节，参见经济评价体系）根据不同的方案及开发指标进行经济评价，
定量评估该油气资产的价值（考虑合同模式和合同条款、合同期限），并据此提
供资产报价意见。
——经济评估软件开发（根据现有的Excel模型编制一个实用的经济评估软
件）
经济模型参数（输入参数）
基本参数 成 本 费用 工作量 产量预测 投资构成
油气价格 资金成本 （大块投资？） 摊销费用 最低义务工作量 勘探投资
价格上涨率 操作成本 管理费用 钻井 钻井投资
原油商品率 钻井成本 财务费用 修井 地面建设投资
贷款利率 销售费用 开发总投资
折现率
定金
租金
矿费
所得税
经济模型指示指标(输出参数)：
内部收益率
净现值
净现值率
投资回收期
最大负现金流
6 风险评估
处于对投资者负责，需要描述一下该项目的风险点，主要包括：
技术风险：地质风险（资料确实，地质认识受限。可能对方资料提供不全或
故意隐瞒）、产量风险（产能、经济极限产能、开发方式适应性）、工程风险等
商业风险：合同变更风险、经济环境风险（价格变动、通货膨胀、外汇风险、
政治环境等等）