Asia's appetite for new refineries undimmed

Asia continues to plan new oil refineries at a faster rate than any other region ( see 'Focus', May 2006 ). The largest increases are taking place in India and China ( see 'Looking Ahead', December 2006 ), but considerable expansion is planned elsewhere across Asia. Up to 3.2 mn bpd of new crude distillation capacity is being planned in other parts of the Asia/Pacific region ( see Table C ), of which nearly 1.1 mn bpd is slated for Indonesia.  

  Table C   Asia/Pacific: Proposed new Refineries     

2.

Refining in the Americas: not enough firm projects     

《Oil and Energy Trends》2008,33(5):13-14

Countries throughout the Western Hemisphere face shortages of refinery capacity, but too few schemes are making it past the drawing-board. OET' s latest refining survey ( see Table E ) shows a large number of projects but many remain tentative and lack firm locations and completion dates: not to mention planning approval and financial backing.  

  Table E   Western Hemisphere: Proposed new refineries     

3.

World's refiners plan massive increase in capacity     

《Oil and Energy Trends》2006,31(5):3-6

Talk of a worldwide shortage of refinery capacity has led to a plethora of new proposals for new refiners and refinery extensions. A survey compiled by Oil and Energy Trends and our associated web-based service Global Energy Review has identified proposals for over 16 mn bpd of new crude distillation capacity ( see Table A ). This represents an increase of nearly 20% over present capacity levels: comfortably over any likely increase in world oil demand over the next decade. It is almost certain, therefore, that some of this planned capacity will not be built. Indeed, some of the proposals for certain individual countries are clearly meant as alternatives to one another. Indonesia and Vietnam, for example, are most unlikely to build more than one new refinery in the next ten years.  

  Table A  World refinery expansion plans     

4.

Non-OPEC production near to decline     

《Oil and Energy Trends》2006,31(4):3-6

Last year, the world produced some 82.2 mn bpd of crude oil and natural gas liquids (NGL), of which 48.2 mn bpd, or 59%, came from countries outside OPEC. Most of these non-OPEC countries are now mature oil-producers, in long term decline ( see Box ). A few have still to reach peak output, but non-OPEC production as a whole is within a few years of its peak, after which any net increase in world oil supplies will have to come entirely from OPEC.  

  NON-OPEC PRODUCERS     

5.

ORIENTING CONVENTIONAL CORES FOR GEOLOGICAL PURPOSES: A REVIEW OF METHODS     

I. Davison  R. S. Haszeldine 《Journal of Petroleum Geology》1984,7(4):461-466

A review of four simple techniques used to re-orient conventional cores back to theri in-situ position in presented. Cores can be oriented by:

• 1. 

  Cutting oriented. cores;
• 2. 

  Using dipmeters;
• 3. 

  Re-orienting in highly deviated holes;
• 4. 

  Using remanent palaeomagnetism.

The accuracy, costs and limitations of the methods are considered.     

6.

FUZZY MODELLING AND THE PREDICTION OF POROSITY AND PERMEABILITY FROM THE COMPOSITIONAL AND TEXTURAL ATTRIBUTES OF SANDSTONE   总被引：4，自引：0，他引：4  

J. H. Fang  H. C. Chen 《Journal of Petroleum Geology》1997,20(2):185-204

A new method is presented here for predicting porosity and permeability from the compositional and textural characteristics of sandstones. The method employs fuzzy modelling which is a linguistic paradigm based on fuzzy logic, rooted in the theory of fuzzy sets. The essentials of fuzzy modelling are explained using an example in which porosity and permeability values of a sandstone are predicted from five compositional and textural attributes. Fuzzy modelling can be accomplished in five steps:

• (i) 

  Identification of input and output variables. In this paper, the inputs are five compositional and textural parameters, namely: relative amounts of ductile grains, rigid grains and detrital matrix, to gether with grain size, and the Trask sorting coefficient. The output is either porosity or permeability.
• (ii) 

  Fuzzy clustering of output values.
• (iii) 

  Formation of membership grades of input data.
• (iv) 

  Generation of fuzzy rules; and
• (v) 

  Prediction via fuzzy inference.

Compared to statistical modelling (i. e. multiple regression analysis), fuzzy modelling is not only assumption-free but is also tolerant of outliers. Fuzzy modelling is capable of making both linguistic and numeric predictions based on qualitative knowledge and/ or quantitative data. Thus, fuzzy modelling is not only appropriate for the problem discussed here, but is also desirable for many geological problems characterized by non-numerical knowledge and imprecise information.     

7.

GEOCHEMISTRY OF CRUDE OIL SAMPLES FROM THE IRANIAN SECTOR OF THE PERSIAN GULF     

A. R. Rabbani 《Journal of Petroleum Geology》2008,31(3):303-316

High-resolution (biomarker) geochemistry combined with other geochemical data has been used to investigate the genetic relationships of 14 crude oil samples from the Iranian sector of the Persian Gulf, and to provide information on the lithologies, palaeo-depositional environments and probable ages of the respective source rocks. Oil samples from the Resalat, Salman, Sirri A, Sirri C, Sirri D and Sirri E fields in the SE of the Gulf, and the Foroozan, Bahregansar, Hendijan, Abouzar, Doroud and Nowrouz fields in the NW of the Gulf were investigated.
Results indicate that the studied oils belong to three genetic groups:

• (i)  

  Group 1 oils (Resalat and Salman fields) were sourced from Jurassic or older, shaly source rocks deposited in a relatively oxic environment;
• (ii)  

  Group 2 oils (Nowrouz, Doroud and Foroozan oilfields) originated from Jurassic or older carbonate-rich source rocks deposited in an anoxic environment;
• (iii)  

  Group 3 oils, which, according to biomarker parameters, were probably sourced from Middle Cretaceous calcareous shales. Two subgroups are recognised: subgroup 3A oils were sampled from oilfields located in the NW of the Gulf (Hendijan, Bahregansar and Abouzar), and subgroup 3B oils came from the south (Sirri A, Sirri C, Sirri D and Sirri E fields).

     

8.

CONTROLS ON THE DISTRIBUTION OF NUMMULITE FACIES: A CASE STUDY FROM THE LATE YPRESIAN EL GARIA FORMATION (KESRA PLATEAU, CENTRAL TUNISIA)     

S. Jorry  E. Davaud  B. Caline 《Journal of Petroleum Geology》2003,26(3):283-306

Eocene nummulite deposits along the southern Tethys margin locally constitute important hydrocarbon reservoir rocks. In order to understand the heterogeneity of these complex reservoirs, we have carried out a detailed field study of the nummulite limestones which crop out at the Kesra Plateau in Central Tunisia. The main contributions of this paper can be summarised as follows:

• (1) 

  Various species of Nummulites and planktonic foraminifera were identified in late Ypresian carbonates in the Kesra area and provided accurate biostratigraphic ages. Nummulitic limestones occur in the Chouabine and El Garia Formations representing deposition over a period of about 2Ma.

       
  
  

9.

GEOLOGICAL INTERPRETATION OF WELL TEST ANALYSIS: A CASE STUDY FROM A FLUVIAL RESERVOIR IN THE GULF OF THAILAND     

S. Y. Zheng  P. W. M. Corbett  A. Emery 《Journal of Petroleum Geology》2003,26(1):49-64

One problem with the inversion of transient well test data is that it can yield a non-unique solution. The uncertainty resulting from this type of approach can only be resolved by considering information from another source such as geology. Geological information will help to define the interpretation model which will ensure the correct analysis of the well test data. The results of well test analyses are of little value to reservoir characterisation and modelling unless they can be explained from a geological point of view. This last step is what we refer to here as geological interpretation. Other sources of information which can help with well test analyses come from seismic surveys and petrophysics. Modern well test interpretation therefore consists of two major steps: analysis of the well test data; and interpretation of the results. In detail, this should include the following:

• (1) 

  definition of an interpretation model — this requires the integration of geological, seismic and petrophysical data with transient pressure data

       
  
  

10.

ANALYSIS OF RESERVES DISCOVERED IN PETROLEUM EXPLORATION     

D. G. Quirk  R. Ruthrauff 《Journal of Petroleum Geology》2006,29(2):125-146

Mathematical theory and empirical data show that discovery sizes from mature plays have lognormal distributions. This allows a simple transformation to be used that converts lognormal trends to straight lines from which valuable statistical data on exploration potential is derived.
After correcting for the unreliable nature of data from non-commercial accumulations and then discounting the extreme high ends and low ends (P1), discovery size distributions from a variety of mature plays outside the Middle East show certain common properties that help constrain reserves ranges in individual prospects and new play fairways. These are:

• •

  P99 is 0.3MM brl or less in non-DHI oil plays and 4BCF or less in gas plays at normal depths;

       
  
  

11.

DETERMINATION OF FAULT SLIP COMPONENTS USING SUBSURFACE STRUCTURAL CONTOURS: METHODS AND EXAMPLES     

S-S. Xu  L. G. Velasquillo-Martinez  J. M. Grajales-Nishimura  G. Murillo-Muñetón  J. García-Hernandez  A. F. Nieto-Samaniego 《Journal of Petroleum Geology》2004,27(3):277-298

Problems with measuring fault slip in the subsurface can sometimes be overcome by using subsurface structural contour maps constructed from well logs and seismic information. These maps are useful for estimating fault slip since fault motion commonly causes the dislocation of structural contours. The dislocation of a contour is defined here as the distance in the direction of fault strike between two contours which have the same value on both sides of a fault. This dislocation can be estimated for tilted beds and folded beds as follows:

• (i) 

  If a dip-slip fault offsets a tilted bed, the dislocation (S_c) of contours can be estimated from the vertical component (S_v) of the fault slip and the dip (β) of the bedding according to the following relationship: S_c= S_v/tan β. Since S_c and β can be measured from a contour map, the vertical component of fault slip can be obtained from this equation.

  If a strike-slip fault offsets a tilted bed, the dislocation (S_cs) of contours is equal to the strike-slip of the fault (S_c), that is, S_cs= S_s.

       
  
  

12.

Technical and Economical Analysis of Hydrogen Sulfide Removal from the Recycled Hydrogen in a Diesel Hydrodesulfurization Plant     

《Petroleum Science and Technology》2013,31(1-2):73-85

Abstract

Hydrodesulfurization (HDS) is a catalytic process used to remove sulfur compounds, which leads to very low sulfur concentrations. HDS turns more complicated and severe according to the feedstock boiling range, since sulfur compounds present in light cuts, normally sulfides and mercaptanes, are easy to remove, and sulfoaromatic compounds, specially polycyclics, are the more refractive ones (Speight, J. G. (1981 Speight, J. G. 1981. The Desulfurization of Heavy Oils and Residua Chemical Industries 4. , 2nd ed. Marcel Dekker Inc.  [Google Scholar]). The Desulfurization of Heavy Oils and Residua. 2nd ed. Marcel Dekker, Inc.: Chemical Industries 4.) The hydrogen sulfide (H₂S) produced in the HDS has an inhibiting effect on the same reaction, as it has been widely observed (McCulloch, D. C. (1983 McCulloch, D. C. 1983. Applied Ind. Catal., I: 69 [Google Scholar]). Applied Ind Catal. I:69; National Petroleum Refining Association (NPRA). (1993 National Petroleum Refining Association, NPRA. 1993. Questions & Answers 99 [Google Scholar]). Questions & Answers, 99; Leglise, J., Van Gestel, J., Duchet, J. C. (1994 Leglise, J., Van Gestel, J. and Duchet, J. C. Symposium on advances in hydrotreating catalysts presented before the division of petroleum chemistry Inc. 208th National Meeting. pp.pp. 533Washington, D.C.: American Chemical Society.  [Google Scholar]). Symposium on Advances in Hydrotreating Catalysts Presented before the Division of Petroleum Chemistry Inc. In: 208th National Meeting American Chemical Society. Washington D.C. p. 533). This effect is well known even at relatively low H₂S concentrations (2 mol%) for commercial operation conditions (Leglise, J., Van Gestel, J., Duchet, J. C. (1994 Leglise, J., Van Gestel, J. and Duchet, J. C. Symposium on advances in hydrotreating catalysts presented before the division of petroleum chemistry Inc. 208th National Meeting. pp.pp. 533Washington, D.C.: American Chemical Society.  [Google Scholar]). Symposium on Advances in Hydrotreating Catalysts Presented before the Division of Petroleum Chemistry Inc. In: 208th National Meeting American Chemical Society. Washington D.C. p. 533). Due to this, the H₂S removal from the recycled hydrogen to the reactor is mandatory in order to increase the desulfurization levels or to increase the processing capacity of an HDS plant. There are many options to low the H₂S concentration in the H₂ loop (Cooper, A., Stanislaus, A., Hannerup, P. N. (June 1993 Cooper, A., Stanislaus, A. and Hannerup, P. N. 1993. Hyd. Process., June: 84 June [Google Scholar]). Hyd Process 84; Johnson, A. D. (1983 Johnson, A. D. 1983. Oil and Gas J., 10: 78 [Google Scholar]). Oil and Gas J 10:78; Nash, R. M. (1989 Nash, R. M. 1989. Oil and Gas J., 13: 47 [Google Scholar]). Oil and Gas J 13:47; Suchanek, A. J., Dave, D., Gupta, A., Van Stralen, H., Karlsson, K. (1993 Suchanek, A. J., Dave, D., Gupta, A., Van Stralen, H. and Karlsson, K. NPRA Annual Meeting. AM-93-24 [Google Scholar]). In: NPRA Annual Meeting AM-93-24; Tippett, T., Knudsen, K. G. (1999 Tippett, T. and Knudsen, K. G. NPRA Annual Meeting. San Antonio, TX. AM-99-06 [Google Scholar]). In: NPRA Annual Meeting. San Antonio, TX. 1999 NPRA Annual Meeting, San Antonio, TX, AM-99-06.), which are from a simple purge adjustment for light naphtha HDS to a full treatment of the H₂ stream for middle distillate HDS, where the H₂S concentration can reach levels of 10 mol% (National Petroleum Refining Association (NPRA). (1993 National Petroleum Refining Association, NPRA. 1993. Questions & Answers 99 [Google Scholar]). Questions & Answers, 99). This work presents the economical analysis of the introduction of an Amine Treating Unit in an HDS plant in operation to remove H₂S from the H₂ stream recycled to the reactor.     

13.

High-temperature adsorption of C7-C13 n-paraffins on MgNaA zeolite     

Yu. P. Ryazantsev  V. V. Kurnoskina 《Chemistry and Technology of Fuels and Oils》1976,12(5):346-349

     

14.

INTERACTIONS BETWEEN TECTONIC ACTIVITY AND EUSTATIC SEA-LEVEL CHANGES IN THE PINDOSAND MESOHELLENIC BASINS, NW GREECE: BASIN EVOLUTION AND HYDROCARBON POTENTIAL     

P. Avramidis  A. Zelilidis  I. Vakalas  N. Kontopoulos 《Journal of Petroleum Geology》2002,25(1):53-82

This paper investigates the sedimentological response of the Tertiary Pindos and Mesohellenic Basins to localized tectonic and eustatic sea-level changes in a submarine setting dominated by turbidite deposition. Five composite stratigraphic cross-sections were compiled from field data, three in the Pindos Basin and two in the Mesohellenic Basin; 45 samples were dated by means of nannofossil bio stratigraphy. On the basis of these field studies, we relate observed changes in depositional environment to eustatic sea-level changes and to activity on local thrusts. Between the early Eocene and the late Miocene, tectonically-driven subsidence in both basins was generally more significant than eustatic variations in controlling depositional patterns. However, depositional conditions can be related to eustatic changes at four specific times:

• (i)

  late Eocene submarine fans and deltaic or fan-delta deposits in the Mesohellenic Basin can be related to a sea-level rise (NP17) and subsequent fall (NP18-19), respectively;

       
  
  

15.

英文摘要     

《石油天然气学报》2010,32(4):I0001-I0007

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16.

英文摘要     

《石油化工设计》2009,26(4)

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17.

英文文摘     

《录井工程》2009,20(4):74-78

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18.

英文摘要     

《石油化工设备技术》2010,31(2):I0001-I0004

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19.

Effect of temperature and concentration of solutions on the position of <Superscript>13</Superscript>C NMR signals for fractions of saturated hydrocarbons forming urea adducts     

M. B. Smirnov  V. A. Melikhov  N. A. Vanyukova 《Petroleum Chemistry》2007,47(1):23-31

An empirical equation was proposed for calculating the chemical shifts of ¹³C NMR signals from monomethylated alkanes and mono-n-alkyl-substituted cyclopentanes and cyclohexanes in the spectra of isoparaffin and naphthene fractions that form adducts with urea, depending on the analyte concentration in deuterochloroform C and the spectrum recording temperature T _rec. Deviations of the calculated chemical shifts from the measured values did not exceed 5 × 10^?3 ppm while varying T _rec from 303 to 323 K and C from 200 to 600 mg/ml. It was shown that such an accuracy is sufficient for the unequivocal identification of components by means of ¹³C NMR technique; ignoring this dependence leads to errors in signal assignment in the spectra of petroleum fractions. The use of the chemical shift of certain signals as internal standards for determination of T _rec and C was proposed. It was assumed that numerical values of the temperature and concentration coefficients that describe the dependence of the chemical shift on T _rec and C would be useful for the ¹³C NMR detection of new groups of compounds in petroleum hydrocarbons.     

20.

英文摘要     

《石油化工设备技术》2010,31(1)

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Refining in the Americas: not enough firm projects

Countries throughout the Western Hemisphere face shortages of refinery capacity, but too few schemes are making it past the drawing-board. OET' s latest refining survey ( see Table E ) shows a large number of projects but many remain tentative and lack firm locations and completion dates: not to mention planning approval and financial backing.  

  Table E   Western Hemisphere: Proposed new refineries     

3.

World's refiners plan massive increase in capacity     

《Oil and Energy Trends》2006,31(5):3-6

Talk of a worldwide shortage of refinery capacity has led to a plethora of new proposals for new refiners and refinery extensions. A survey compiled by Oil and Energy Trends and our associated web-based service Global Energy Review has identified proposals for over 16 mn bpd of new crude distillation capacity ( see Table A ). This represents an increase of nearly 20% over present capacity levels: comfortably over any likely increase in world oil demand over the next decade. It is almost certain, therefore, that some of this planned capacity will not be built. Indeed, some of the proposals for certain individual countries are clearly meant as alternatives to one another. Indonesia and Vietnam, for example, are most unlikely to build more than one new refinery in the next ten years.  

  Table A  World refinery expansion plans     

4.

Non-OPEC production near to decline     

《Oil and Energy Trends》2006,31(4):3-6

Last year, the world produced some 82.2 mn bpd of crude oil and natural gas liquids (NGL), of which 48.2 mn bpd, or 59%, came from countries outside OPEC. Most of these non-OPEC countries are now mature oil-producers, in long term decline ( see Box ). A few have still to reach peak output, but non-OPEC production as a whole is within a few years of its peak, after which any net increase in world oil supplies will have to come entirely from OPEC.  

  NON-OPEC PRODUCERS     

5.

ORIENTING CONVENTIONAL CORES FOR GEOLOGICAL PURPOSES: A REVIEW OF METHODS     

I. Davison  R. S. Haszeldine 《Journal of Petroleum Geology》1984,7(4):461-466

A review of four simple techniques used to re-orient conventional cores back to theri in-situ position in presented. Cores can be oriented by:

• 1. 

  Cutting oriented. cores;
• 2. 

  Using dipmeters;
• 3. 

  Re-orienting in highly deviated holes;
• 4. 

  Using remanent palaeomagnetism.

The accuracy, costs and limitations of the methods are considered.     

6.

FUZZY MODELLING AND THE PREDICTION OF POROSITY AND PERMEABILITY FROM THE COMPOSITIONAL AND TEXTURAL ATTRIBUTES OF SANDSTONE   总被引：4，自引：0，他引：4  

J. H. Fang  H. C. Chen 《Journal of Petroleum Geology》1997,20(2):185-204

A new method is presented here for predicting porosity and permeability from the compositional and textural characteristics of sandstones. The method employs fuzzy modelling which is a linguistic paradigm based on fuzzy logic, rooted in the theory of fuzzy sets. The essentials of fuzzy modelling are explained using an example in which porosity and permeability values of a sandstone are predicted from five compositional and textural attributes. Fuzzy modelling can be accomplished in five steps:

• (i) 

  Identification of input and output variables. In this paper, the inputs are five compositional and textural parameters, namely: relative amounts of ductile grains, rigid grains and detrital matrix, to gether with grain size, and the Trask sorting coefficient. The output is either porosity or permeability.
• (ii) 

  Fuzzy clustering of output values.
• (iii) 

  Formation of membership grades of input data.
• (iv) 

  Generation of fuzzy rules; and
• (v) 

  Prediction via fuzzy inference.

Compared to statistical modelling (i. e. multiple regression analysis), fuzzy modelling is not only assumption-free but is also tolerant of outliers. Fuzzy modelling is capable of making both linguistic and numeric predictions based on qualitative knowledge and/ or quantitative data. Thus, fuzzy modelling is not only appropriate for the problem discussed here, but is also desirable for many geological problems characterized by non-numerical knowledge and imprecise information.     

7.

GEOCHEMISTRY OF CRUDE OIL SAMPLES FROM THE IRANIAN SECTOR OF THE PERSIAN GULF     

A. R. Rabbani 《Journal of Petroleum Geology》2008,31(3):303-316

High-resolution (biomarker) geochemistry combined with other geochemical data has been used to investigate the genetic relationships of 14 crude oil samples from the Iranian sector of the Persian Gulf, and to provide information on the lithologies, palaeo-depositional environments and probable ages of the respective source rocks. Oil samples from the Resalat, Salman, Sirri A, Sirri C, Sirri D and Sirri E fields in the SE of the Gulf, and the Foroozan, Bahregansar, Hendijan, Abouzar, Doroud and Nowrouz fields in the NW of the Gulf were investigated.
Results indicate that the studied oils belong to three genetic groups:

• (i)  

  Group 1 oils (Resalat and Salman fields) were sourced from Jurassic or older, shaly source rocks deposited in a relatively oxic environment;
• (ii)  

  Group 2 oils (Nowrouz, Doroud and Foroozan oilfields) originated from Jurassic or older carbonate-rich source rocks deposited in an anoxic environment;
• (iii)  

  Group 3 oils, which, according to biomarker parameters, were probably sourced from Middle Cretaceous calcareous shales. Two subgroups are recognised: subgroup 3A oils were sampled from oilfields located in the NW of the Gulf (Hendijan, Bahregansar and Abouzar), and subgroup 3B oils came from the south (Sirri A, Sirri C, Sirri D and Sirri E fields).

     

8.

CONTROLS ON THE DISTRIBUTION OF NUMMULITE FACIES: A CASE STUDY FROM THE LATE YPRESIAN EL GARIA FORMATION (KESRA PLATEAU, CENTRAL TUNISIA)     

S. Jorry  E. Davaud  B. Caline 《Journal of Petroleum Geology》2003,26(3):283-306

Eocene nummulite deposits along the southern Tethys margin locally constitute important hydrocarbon reservoir rocks. In order to understand the heterogeneity of these complex reservoirs, we have carried out a detailed field study of the nummulite limestones which crop out at the Kesra Plateau in Central Tunisia. The main contributions of this paper can be summarised as follows:

• (1) 

  Various species of Nummulites and planktonic foraminifera were identified in late Ypresian carbonates in the Kesra area and provided accurate biostratigraphic ages. Nummulitic limestones occur in the Chouabine and El Garia Formations representing deposition over a period of about 2Ma.

       
  
  

9.

GEOLOGICAL INTERPRETATION OF WELL TEST ANALYSIS: A CASE STUDY FROM A FLUVIAL RESERVOIR IN THE GULF OF THAILAND     

S. Y. Zheng  P. W. M. Corbett  A. Emery 《Journal of Petroleum Geology》2003,26(1):49-64

One problem with the inversion of transient well test data is that it can yield a non-unique solution. The uncertainty resulting from this type of approach can only be resolved by considering information from another source such as geology. Geological information will help to define the interpretation model which will ensure the correct analysis of the well test data. The results of well test analyses are of little value to reservoir characterisation and modelling unless they can be explained from a geological point of view. This last step is what we refer to here as geological interpretation. Other sources of information which can help with well test analyses come from seismic surveys and petrophysics. Modern well test interpretation therefore consists of two major steps: analysis of the well test data; and interpretation of the results. In detail, this should include the following:

• (1) 

  definition of an interpretation model — this requires the integration of geological, seismic and petrophysical data with transient pressure data

       
  
  

10.

ANALYSIS OF RESERVES DISCOVERED IN PETROLEUM EXPLORATION     

D. G. Quirk  R. Ruthrauff 《Journal of Petroleum Geology》2006,29(2):125-146

Mathematical theory and empirical data show that discovery sizes from mature plays have lognormal distributions. This allows a simple transformation to be used that converts lognormal trends to straight lines from which valuable statistical data on exploration potential is derived.
After correcting for the unreliable nature of data from non-commercial accumulations and then discounting the extreme high ends and low ends (P1), discovery size distributions from a variety of mature plays outside the Middle East show certain common properties that help constrain reserves ranges in individual prospects and new play fairways. These are:

• •

  P99 is 0.3MM brl or less in non-DHI oil plays and 4BCF or less in gas plays at normal depths;

       
  
  

11.

DETERMINATION OF FAULT SLIP COMPONENTS USING SUBSURFACE STRUCTURAL CONTOURS: METHODS AND EXAMPLES     

S-S. Xu  L. G. Velasquillo-Martinez  J. M. Grajales-Nishimura  G. Murillo-Muñetón  J. García-Hernandez  A. F. Nieto-Samaniego 《Journal of Petroleum Geology》2004,27(3):277-298

Problems with measuring fault slip in the subsurface can sometimes be overcome by using subsurface structural contour maps constructed from well logs and seismic information. These maps are useful for estimating fault slip since fault motion commonly causes the dislocation of structural contours. The dislocation of a contour is defined here as the distance in the direction of fault strike between two contours which have the same value on both sides of a fault. This dislocation can be estimated for tilted beds and folded beds as follows:

• (i) 

  If a dip-slip fault offsets a tilted bed, the dislocation (S_c) of contours can be estimated from the vertical component (S_v) of the fault slip and the dip (β) of the bedding according to the following relationship: S_c= S_v/tan β. Since S_c and β can be measured from a contour map, the vertical component of fault slip can be obtained from this equation.

  If a strike-slip fault offsets a tilted bed, the dislocation (S_cs) of contours is equal to the strike-slip of the fault (S_c), that is, S_cs= S_s.

       
  
  

12.

Technical and Economical Analysis of Hydrogen Sulfide Removal from the Recycled Hydrogen in a Diesel Hydrodesulfurization Plant     

《Petroleum Science and Technology》2013,31(1-2):73-85

Abstract

Hydrodesulfurization (HDS) is a catalytic process used to remove sulfur compounds, which leads to very low sulfur concentrations. HDS turns more complicated and severe according to the feedstock boiling range, since sulfur compounds present in light cuts, normally sulfides and mercaptanes, are easy to remove, and sulfoaromatic compounds, specially polycyclics, are the more refractive ones (Speight, J. G. (1981 Speight, J. G. 1981. The Desulfurization of Heavy Oils and Residua Chemical Industries 4. , 2nd ed. Marcel Dekker Inc.  [Google Scholar]). The Desulfurization of Heavy Oils and Residua. 2nd ed. Marcel Dekker, Inc.: Chemical Industries 4.) The hydrogen sulfide (H₂S) produced in the HDS has an inhibiting effect on the same reaction, as it has been widely observed (McCulloch, D. C. (1983 McCulloch, D. C. 1983. Applied Ind. Catal., I: 69 [Google Scholar]). Applied Ind Catal. I:69; National Petroleum Refining Association (NPRA). (1993 National Petroleum Refining Association, NPRA. 1993. Questions & Answers 99 [Google Scholar]). Questions & Answers, 99; Leglise, J., Van Gestel, J., Duchet, J. C. (1994 Leglise, J., Van Gestel, J. and Duchet, J. C. Symposium on advances in hydrotreating catalysts presented before the division of petroleum chemistry Inc. 208th National Meeting. pp.pp. 533Washington, D.C.: American Chemical Society.  [Google Scholar]). Symposium on Advances in Hydrotreating Catalysts Presented before the Division of Petroleum Chemistry Inc. In: 208th National Meeting American Chemical Society. Washington D.C. p. 533). This effect is well known even at relatively low H₂S concentrations (2 mol%) for commercial operation conditions (Leglise, J., Van Gestel, J., Duchet, J. C. (1994 Leglise, J., Van Gestel, J. and Duchet, J. C. Symposium on advances in hydrotreating catalysts presented before the division of petroleum chemistry Inc. 208th National Meeting. pp.pp. 533Washington, D.C.: American Chemical Society.  [Google Scholar]). Symposium on Advances in Hydrotreating Catalysts Presented before the Division of Petroleum Chemistry Inc. In: 208th National Meeting American Chemical Society. Washington D.C. p. 533). Due to this, the H₂S removal from the recycled hydrogen to the reactor is mandatory in order to increase the desulfurization levels or to increase the processing capacity of an HDS plant. There are many options to low the H₂S concentration in the H₂ loop (Cooper, A., Stanislaus, A., Hannerup, P. N. (June 1993 Cooper, A., Stanislaus, A. and Hannerup, P. N. 1993. Hyd. Process., June: 84 June [Google Scholar]). Hyd Process 84; Johnson, A. D. (1983 Johnson, A. D. 1983. Oil and Gas J., 10: 78 [Google Scholar]). Oil and Gas J 10:78; Nash, R. M. (1989 Nash, R. M. 1989. Oil and Gas J., 13: 47 [Google Scholar]). Oil and Gas J 13:47; Suchanek, A. J., Dave, D., Gupta, A., Van Stralen, H., Karlsson, K. (1993 Suchanek, A. J., Dave, D., Gupta, A., Van Stralen, H. and Karlsson, K. NPRA Annual Meeting. AM-93-24 [Google Scholar]). In: NPRA Annual Meeting AM-93-24; Tippett, T., Knudsen, K. G. (1999 Tippett, T. and Knudsen, K. G. NPRA Annual Meeting. San Antonio, TX. AM-99-06 [Google Scholar]). In: NPRA Annual Meeting. San Antonio, TX. 1999 NPRA Annual Meeting, San Antonio, TX, AM-99-06.), which are from a simple purge adjustment for light naphtha HDS to a full treatment of the H₂ stream for middle distillate HDS, where the H₂S concentration can reach levels of 10 mol% (National Petroleum Refining Association (NPRA). (1993 National Petroleum Refining Association, NPRA. 1993. Questions & Answers 99 [Google Scholar]). Questions & Answers, 99). This work presents the economical analysis of the introduction of an Amine Treating Unit in an HDS plant in operation to remove H₂S from the H₂ stream recycled to the reactor.     

13.

High-temperature adsorption of C7-C13 n-paraffins on MgNaA zeolite     

Yu. P. Ryazantsev  V. V. Kurnoskina 《Chemistry and Technology of Fuels and Oils》1976,12(5):346-349

     

14.

INTERACTIONS BETWEEN TECTONIC ACTIVITY AND EUSTATIC SEA-LEVEL CHANGES IN THE PINDOSAND MESOHELLENIC BASINS, NW GREECE: BASIN EVOLUTION AND HYDROCARBON POTENTIAL     

P. Avramidis  A. Zelilidis  I. Vakalas  N. Kontopoulos 《Journal of Petroleum Geology》2002,25(1):53-82

This paper investigates the sedimentological response of the Tertiary Pindos and Mesohellenic Basins to localized tectonic and eustatic sea-level changes in a submarine setting dominated by turbidite deposition. Five composite stratigraphic cross-sections were compiled from field data, three in the Pindos Basin and two in the Mesohellenic Basin; 45 samples were dated by means of nannofossil bio stratigraphy. On the basis of these field studies, we relate observed changes in depositional environment to eustatic sea-level changes and to activity on local thrusts. Between the early Eocene and the late Miocene, tectonically-driven subsidence in both basins was generally more significant than eustatic variations in controlling depositional patterns. However, depositional conditions can be related to eustatic changes at four specific times:

• (i)

  late Eocene submarine fans and deltaic or fan-delta deposits in the Mesohellenic Basin can be related to a sea-level rise (NP17) and subsequent fall (NP18-19), respectively;

       
  
  

15.

英文摘要     

《石油天然气学报》2010,32(4):I0001-I0007

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16.

英文摘要     

《石油化工设计》2009,26(4)

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17.

英文文摘     

《录井工程》2009,20(4):74-78

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18.

英文摘要     

《石油化工设备技术》2010,31(2):I0001-I0004

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19.

Effect of temperature and concentration of solutions on the position of <Superscript>13</Superscript>C NMR signals for fractions of saturated hydrocarbons forming urea adducts     

M. B. Smirnov  V. A. Melikhov  N. A. Vanyukova 《Petroleum Chemistry》2007,47(1):23-31

An empirical equation was proposed for calculating the chemical shifts of ¹³C NMR signals from monomethylated alkanes and mono-n-alkyl-substituted cyclopentanes and cyclohexanes in the spectra of isoparaffin and naphthene fractions that form adducts with urea, depending on the analyte concentration in deuterochloroform C and the spectrum recording temperature T _rec. Deviations of the calculated chemical shifts from the measured values did not exceed 5 × 10^?3 ppm while varying T _rec from 303 to 323 K and C from 200 to 600 mg/ml. It was shown that such an accuracy is sufficient for the unequivocal identification of components by means of ¹³C NMR technique; ignoring this dependence leads to errors in signal assignment in the spectra of petroleum fractions. The use of the chemical shift of certain signals as internal standards for determination of T _rec and C was proposed. It was assumed that numerical values of the temperature and concentration coefficients that describe the dependence of the chemical shift on T _rec and C would be useful for the ¹³C NMR detection of new groups of compounds in petroleum hydrocarbons.     

20.

英文摘要     

《石油化工设备技术》2010,31(1)

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World's refiners plan massive increase in capacity

Talk of a worldwide shortage of refinery capacity has led to a plethora of new proposals for new refiners and refinery extensions. A survey compiled by Oil and Energy Trends and our associated web-based service Global Energy Review has identified proposals for over 16 mn bpd of new crude distillation capacity ( see Table A ). This represents an increase of nearly 20% over present capacity levels: comfortably over any likely increase in world oil demand over the next decade. It is almost certain, therefore, that some of this planned capacity will not be built. Indeed, some of the proposals for certain individual countries are clearly meant as alternatives to one another. Indonesia and Vietnam, for example, are most unlikely to build more than one new refinery in the next ten years.  

  Table A  World refinery expansion plans     

4.

Non-OPEC production near to decline     

《Oil and Energy Trends》2006,31(4):3-6

Last year, the world produced some 82.2 mn bpd of crude oil and natural gas liquids (NGL), of which 48.2 mn bpd, or 59%, came from countries outside OPEC. Most of these non-OPEC countries are now mature oil-producers, in long term decline ( see Box ). A few have still to reach peak output, but non-OPEC production as a whole is within a few years of its peak, after which any net increase in world oil supplies will have to come entirely from OPEC.  

  NON-OPEC PRODUCERS     

5.

ORIENTING CONVENTIONAL CORES FOR GEOLOGICAL PURPOSES: A REVIEW OF METHODS     

I. Davison  R. S. Haszeldine 《Journal of Petroleum Geology》1984,7(4):461-466

A review of four simple techniques used to re-orient conventional cores back to theri in-situ position in presented. Cores can be oriented by:

• 1. 

  Cutting oriented. cores;
• 2. 

  Using dipmeters;
• 3. 

  Re-orienting in highly deviated holes;
• 4. 

  Using remanent palaeomagnetism.

The accuracy, costs and limitations of the methods are considered.     

6.

FUZZY MODELLING AND THE PREDICTION OF POROSITY AND PERMEABILITY FROM THE COMPOSITIONAL AND TEXTURAL ATTRIBUTES OF SANDSTONE   总被引：4，自引：0，他引：4  

J. H. Fang  H. C. Chen 《Journal of Petroleum Geology》1997,20(2):185-204

A new method is presented here for predicting porosity and permeability from the compositional and textural characteristics of sandstones. The method employs fuzzy modelling which is a linguistic paradigm based on fuzzy logic, rooted in the theory of fuzzy sets. The essentials of fuzzy modelling are explained using an example in which porosity and permeability values of a sandstone are predicted from five compositional and textural attributes. Fuzzy modelling can be accomplished in five steps:

• (i) 

  Identification of input and output variables. In this paper, the inputs are five compositional and textural parameters, namely: relative amounts of ductile grains, rigid grains and detrital matrix, to gether with grain size, and the Trask sorting coefficient. The output is either porosity or permeability.
• (ii) 

  Fuzzy clustering of output values.
• (iii) 

  Formation of membership grades of input data.
• (iv) 

  Generation of fuzzy rules; and
• (v) 

  Prediction via fuzzy inference.

Compared to statistical modelling (i. e. multiple regression analysis), fuzzy modelling is not only assumption-free but is also tolerant of outliers. Fuzzy modelling is capable of making both linguistic and numeric predictions based on qualitative knowledge and/ or quantitative data. Thus, fuzzy modelling is not only appropriate for the problem discussed here, but is also desirable for many geological problems characterized by non-numerical knowledge and imprecise information.     

7.

GEOCHEMISTRY OF CRUDE OIL SAMPLES FROM THE IRANIAN SECTOR OF THE PERSIAN GULF     

A. R. Rabbani 《Journal of Petroleum Geology》2008,31(3):303-316

High-resolution (biomarker) geochemistry combined with other geochemical data has been used to investigate the genetic relationships of 14 crude oil samples from the Iranian sector of the Persian Gulf, and to provide information on the lithologies, palaeo-depositional environments and probable ages of the respective source rocks. Oil samples from the Resalat, Salman, Sirri A, Sirri C, Sirri D and Sirri E fields in the SE of the Gulf, and the Foroozan, Bahregansar, Hendijan, Abouzar, Doroud and Nowrouz fields in the NW of the Gulf were investigated.
Results indicate that the studied oils belong to three genetic groups:

• (i)  

  Group 1 oils (Resalat and Salman fields) were sourced from Jurassic or older, shaly source rocks deposited in a relatively oxic environment;
• (ii)  

  Group 2 oils (Nowrouz, Doroud and Foroozan oilfields) originated from Jurassic or older carbonate-rich source rocks deposited in an anoxic environment;
• (iii)  

  Group 3 oils, which, according to biomarker parameters, were probably sourced from Middle Cretaceous calcareous shales. Two subgroups are recognised: subgroup 3A oils were sampled from oilfields located in the NW of the Gulf (Hendijan, Bahregansar and Abouzar), and subgroup 3B oils came from the south (Sirri A, Sirri C, Sirri D and Sirri E fields).

     

8.

CONTROLS ON THE DISTRIBUTION OF NUMMULITE FACIES: A CASE STUDY FROM THE LATE YPRESIAN EL GARIA FORMATION (KESRA PLATEAU, CENTRAL TUNISIA)     

S. Jorry  E. Davaud  B. Caline 《Journal of Petroleum Geology》2003,26(3):283-306

Eocene nummulite deposits along the southern Tethys margin locally constitute important hydrocarbon reservoir rocks. In order to understand the heterogeneity of these complex reservoirs, we have carried out a detailed field study of the nummulite limestones which crop out at the Kesra Plateau in Central Tunisia. The main contributions of this paper can be summarised as follows:

• (1) 

  Various species of Nummulites and planktonic foraminifera were identified in late Ypresian carbonates in the Kesra area and provided accurate biostratigraphic ages. Nummulitic limestones occur in the Chouabine and El Garia Formations representing deposition over a period of about 2Ma.

       
  
  

9.

GEOLOGICAL INTERPRETATION OF WELL TEST ANALYSIS: A CASE STUDY FROM A FLUVIAL RESERVOIR IN THE GULF OF THAILAND     

S. Y. Zheng  P. W. M. Corbett  A. Emery 《Journal of Petroleum Geology》2003,26(1):49-64

One problem with the inversion of transient well test data is that it can yield a non-unique solution. The uncertainty resulting from this type of approach can only be resolved by considering information from another source such as geology. Geological information will help to define the interpretation model which will ensure the correct analysis of the well test data. The results of well test analyses are of little value to reservoir characterisation and modelling unless they can be explained from a geological point of view. This last step is what we refer to here as geological interpretation. Other sources of information which can help with well test analyses come from seismic surveys and petrophysics. Modern well test interpretation therefore consists of two major steps: analysis of the well test data; and interpretation of the results. In detail, this should include the following:

• (1) 

  definition of an interpretation model — this requires the integration of geological, seismic and petrophysical data with transient pressure data

       
  
  

10.

ANALYSIS OF RESERVES DISCOVERED IN PETROLEUM EXPLORATION     

D. G. Quirk  R. Ruthrauff 《Journal of Petroleum Geology》2006,29(2):125-146

Mathematical theory and empirical data show that discovery sizes from mature plays have lognormal distributions. This allows a simple transformation to be used that converts lognormal trends to straight lines from which valuable statistical data on exploration potential is derived.
After correcting for the unreliable nature of data from non-commercial accumulations and then discounting the extreme high ends and low ends (P1), discovery size distributions from a variety of mature plays outside the Middle East show certain common properties that help constrain reserves ranges in individual prospects and new play fairways. These are:

• •

  P99 is 0.3MM brl or less in non-DHI oil plays and 4BCF or less in gas plays at normal depths;

       
  
  

11.

DETERMINATION OF FAULT SLIP COMPONENTS USING SUBSURFACE STRUCTURAL CONTOURS: METHODS AND EXAMPLES     

S-S. Xu  L. G. Velasquillo-Martinez  J. M. Grajales-Nishimura  G. Murillo-Muñetón  J. García-Hernandez  A. F. Nieto-Samaniego 《Journal of Petroleum Geology》2004,27(3):277-298

Problems with measuring fault slip in the subsurface can sometimes be overcome by using subsurface structural contour maps constructed from well logs and seismic information. These maps are useful for estimating fault slip since fault motion commonly causes the dislocation of structural contours. The dislocation of a contour is defined here as the distance in the direction of fault strike between two contours which have the same value on both sides of a fault. This dislocation can be estimated for tilted beds and folded beds as follows:

• (i) 

  If a dip-slip fault offsets a tilted bed, the dislocation (S_c) of contours can be estimated from the vertical component (S_v) of the fault slip and the dip (β) of the bedding according to the following relationship: S_c= S_v/tan β. Since S_c and β can be measured from a contour map, the vertical component of fault slip can be obtained from this equation.

  If a strike-slip fault offsets a tilted bed, the dislocation (S_cs) of contours is equal to the strike-slip of the fault (S_c), that is, S_cs= S_s.

       
  
  

12.

Technical and Economical Analysis of Hydrogen Sulfide Removal from the Recycled Hydrogen in a Diesel Hydrodesulfurization Plant     

《Petroleum Science and Technology》2013,31(1-2):73-85

Abstract

Hydrodesulfurization (HDS) is a catalytic process used to remove sulfur compounds, which leads to very low sulfur concentrations. HDS turns more complicated and severe according to the feedstock boiling range, since sulfur compounds present in light cuts, normally sulfides and mercaptanes, are easy to remove, and sulfoaromatic compounds, specially polycyclics, are the more refractive ones (Speight, J. G. (1981 Speight, J. G. 1981. The Desulfurization of Heavy Oils and Residua Chemical Industries 4. , 2nd ed. Marcel Dekker Inc.  [Google Scholar]). The Desulfurization of Heavy Oils and Residua. 2nd ed. Marcel Dekker, Inc.: Chemical Industries 4.) The hydrogen sulfide (H₂S) produced in the HDS has an inhibiting effect on the same reaction, as it has been widely observed (McCulloch, D. C. (1983 McCulloch, D. C. 1983. Applied Ind. Catal., I: 69 [Google Scholar]). Applied Ind Catal. I:69; National Petroleum Refining Association (NPRA). (1993 National Petroleum Refining Association, NPRA. 1993. Questions & Answers 99 [Google Scholar]). Questions & Answers, 99; Leglise, J., Van Gestel, J., Duchet, J. C. (1994 Leglise, J., Van Gestel, J. and Duchet, J. C. Symposium on advances in hydrotreating catalysts presented before the division of petroleum chemistry Inc. 208th National Meeting. pp.pp. 533Washington, D.C.: American Chemical Society.  [Google Scholar]). Symposium on Advances in Hydrotreating Catalysts Presented before the Division of Petroleum Chemistry Inc. In: 208th National Meeting American Chemical Society. Washington D.C. p. 533). This effect is well known even at relatively low H₂S concentrations (2 mol%) for commercial operation conditions (Leglise, J., Van Gestel, J., Duchet, J. C. (1994 Leglise, J., Van Gestel, J. and Duchet, J. C. Symposium on advances in hydrotreating catalysts presented before the division of petroleum chemistry Inc. 208th National Meeting. pp.pp. 533Washington, D.C.: American Chemical Society.  [Google Scholar]). Symposium on Advances in Hydrotreating Catalysts Presented before the Division of Petroleum Chemistry Inc. In: 208th National Meeting American Chemical Society. Washington D.C. p. 533). Due to this, the H₂S removal from the recycled hydrogen to the reactor is mandatory in order to increase the desulfurization levels or to increase the processing capacity of an HDS plant. There are many options to low the H₂S concentration in the H₂ loop (Cooper, A., Stanislaus, A., Hannerup, P. N. (June 1993 Cooper, A., Stanislaus, A. and Hannerup, P. N. 1993. Hyd. Process., June: 84 June [Google Scholar]). Hyd Process 84; Johnson, A. D. (1983 Johnson, A. D. 1983. Oil and Gas J., 10: 78 [Google Scholar]). Oil and Gas J 10:78; Nash, R. M. (1989 Nash, R. M. 1989. Oil and Gas J., 13: 47 [Google Scholar]). Oil and Gas J 13:47; Suchanek, A. J., Dave, D., Gupta, A., Van Stralen, H., Karlsson, K. (1993 Suchanek, A. J., Dave, D., Gupta, A., Van Stralen, H. and Karlsson, K. NPRA Annual Meeting. AM-93-24 [Google Scholar]). In: NPRA Annual Meeting AM-93-24; Tippett, T., Knudsen, K. G. (1999 Tippett, T. and Knudsen, K. G. NPRA Annual Meeting. San Antonio, TX. AM-99-06 [Google Scholar]). In: NPRA Annual Meeting. San Antonio, TX. 1999 NPRA Annual Meeting, San Antonio, TX, AM-99-06.), which are from a simple purge adjustment for light naphtha HDS to a full treatment of the H₂ stream for middle distillate HDS, where the H₂S concentration can reach levels of 10 mol% (National Petroleum Refining Association (NPRA). (1993 National Petroleum Refining Association, NPRA. 1993. Questions & Answers 99 [Google Scholar]). Questions & Answers, 99). This work presents the economical analysis of the introduction of an Amine Treating Unit in an HDS plant in operation to remove H₂S from the H₂ stream recycled to the reactor.     

13.

High-temperature adsorption of C7-C13 n-paraffins on MgNaA zeolite     

Yu. P. Ryazantsev  V. V. Kurnoskina 《Chemistry and Technology of Fuels and Oils》1976,12(5):346-349

     

14.

INTERACTIONS BETWEEN TECTONIC ACTIVITY AND EUSTATIC SEA-LEVEL CHANGES IN THE PINDOSAND MESOHELLENIC BASINS, NW GREECE: BASIN EVOLUTION AND HYDROCARBON POTENTIAL     

P. Avramidis  A. Zelilidis  I. Vakalas  N. Kontopoulos 《Journal of Petroleum Geology》2002,25(1):53-82

This paper investigates the sedimentological response of the Tertiary Pindos and Mesohellenic Basins to localized tectonic and eustatic sea-level changes in a submarine setting dominated by turbidite deposition. Five composite stratigraphic cross-sections were compiled from field data, three in the Pindos Basin and two in the Mesohellenic Basin; 45 samples were dated by means of nannofossil bio stratigraphy. On the basis of these field studies, we relate observed changes in depositional environment to eustatic sea-level changes and to activity on local thrusts. Between the early Eocene and the late Miocene, tectonically-driven subsidence in both basins was generally more significant than eustatic variations in controlling depositional patterns. However, depositional conditions can be related to eustatic changes at four specific times:

• (i)

  late Eocene submarine fans and deltaic or fan-delta deposits in the Mesohellenic Basin can be related to a sea-level rise (NP17) and subsequent fall (NP18-19), respectively;

       
  
  

15.

英文摘要     

《石油天然气学报》2010,32(4):I0001-I0007

查看全文 下载全文     

16.

英文摘要     

《石油化工设计》2009,26(4)

查看全文 下载全文     

17.

英文文摘     

《录井工程》2009,20(4):74-78

查看全文 下载全文     

18.

英文摘要     

《石油化工设备技术》2010,31(2):I0001-I0004

查看全文 下载全文     

19.

Effect of temperature and concentration of solutions on the position of <Superscript>13</Superscript>C NMR signals for fractions of saturated hydrocarbons forming urea adducts     

M. B. Smirnov  V. A. Melikhov  N. A. Vanyukova 《Petroleum Chemistry》2007,47(1):23-31

An empirical equation was proposed for calculating the chemical shifts of ¹³C NMR signals from monomethylated alkanes and mono-n-alkyl-substituted cyclopentanes and cyclohexanes in the spectra of isoparaffin and naphthene fractions that form adducts with urea, depending on the analyte concentration in deuterochloroform C and the spectrum recording temperature T _rec. Deviations of the calculated chemical shifts from the measured values did not exceed 5 × 10^?3 ppm while varying T _rec from 303 to 323 K and C from 200 to 600 mg/ml. It was shown that such an accuracy is sufficient for the unequivocal identification of components by means of ¹³C NMR technique; ignoring this dependence leads to errors in signal assignment in the spectra of petroleum fractions. The use of the chemical shift of certain signals as internal standards for determination of T _rec and C was proposed. It was assumed that numerical values of the temperature and concentration coefficients that describe the dependence of the chemical shift on T _rec and C would be useful for the ¹³C NMR detection of new groups of compounds in petroleum hydrocarbons.     

20.

英文摘要     

《石油化工设备技术》2010,31(1)

查看全文 下载全文     

Non-OPEC production near to decline

Last year, the world produced some 82.2 mn bpd of crude oil and natural gas liquids (NGL), of which 48.2 mn bpd, or 59%, came from countries outside OPEC. Most of these non-OPEC countries are now mature oil-producers, in long term decline ( see Box ). A few have still to reach peak output, but non-OPEC production as a whole is within a few years of its peak, after which any net increase in world oil supplies will have to come entirely from OPEC.  

  NON-OPEC PRODUCERS     

5.

ORIENTING CONVENTIONAL CORES FOR GEOLOGICAL PURPOSES: A REVIEW OF METHODS     

I. Davison  R. S. Haszeldine 《Journal of Petroleum Geology》1984,7(4):461-466

A review of four simple techniques used to re-orient conventional cores back to theri in-situ position in presented. Cores can be oriented by:

• 1. 

  Cutting oriented. cores;
• 2. 

  Using dipmeters;
• 3. 

  Re-orienting in highly deviated holes;
• 4. 

  Using remanent palaeomagnetism.

The accuracy, costs and limitations of the methods are considered.     

6.

FUZZY MODELLING AND THE PREDICTION OF POROSITY AND PERMEABILITY FROM THE COMPOSITIONAL AND TEXTURAL ATTRIBUTES OF SANDSTONE   总被引：4，自引：0，他引：4  

J. H. Fang  H. C. Chen 《Journal of Petroleum Geology》1997,20(2):185-204

A new method is presented here for predicting porosity and permeability from the compositional and textural characteristics of sandstones. The method employs fuzzy modelling which is a linguistic paradigm based on fuzzy logic, rooted in the theory of fuzzy sets. The essentials of fuzzy modelling are explained using an example in which porosity and permeability values of a sandstone are predicted from five compositional and textural attributes. Fuzzy modelling can be accomplished in five steps:

• (i) 

  Identification of input and output variables. In this paper, the inputs are five compositional and textural parameters, namely: relative amounts of ductile grains, rigid grains and detrital matrix, to gether with grain size, and the Trask sorting coefficient. The output is either porosity or permeability.
• (ii) 

  Fuzzy clustering of output values.
• (iii) 

  Formation of membership grades of input data.
• (iv) 

  Generation of fuzzy rules; and
• (v) 

  Prediction via fuzzy inference.

Compared to statistical modelling (i. e. multiple regression analysis), fuzzy modelling is not only assumption-free but is also tolerant of outliers. Fuzzy modelling is capable of making both linguistic and numeric predictions based on qualitative knowledge and/ or quantitative data. Thus, fuzzy modelling is not only appropriate for the problem discussed here, but is also desirable for many geological problems characterized by non-numerical knowledge and imprecise information.     

7.

GEOCHEMISTRY OF CRUDE OIL SAMPLES FROM THE IRANIAN SECTOR OF THE PERSIAN GULF     

A. R. Rabbani 《Journal of Petroleum Geology》2008,31(3):303-316

High-resolution (biomarker) geochemistry combined with other geochemical data has been used to investigate the genetic relationships of 14 crude oil samples from the Iranian sector of the Persian Gulf, and to provide information on the lithologies, palaeo-depositional environments and probable ages of the respective source rocks. Oil samples from the Resalat, Salman, Sirri A, Sirri C, Sirri D and Sirri E fields in the SE of the Gulf, and the Foroozan, Bahregansar, Hendijan, Abouzar, Doroud and Nowrouz fields in the NW of the Gulf were investigated.
Results indicate that the studied oils belong to three genetic groups:

• (i)  

  Group 1 oils (Resalat and Salman fields) were sourced from Jurassic or older, shaly source rocks deposited in a relatively oxic environment;
• (ii)  

  Group 2 oils (Nowrouz, Doroud and Foroozan oilfields) originated from Jurassic or older carbonate-rich source rocks deposited in an anoxic environment;
• (iii)  

  Group 3 oils, which, according to biomarker parameters, were probably sourced from Middle Cretaceous calcareous shales. Two subgroups are recognised: subgroup 3A oils were sampled from oilfields located in the NW of the Gulf (Hendijan, Bahregansar and Abouzar), and subgroup 3B oils came from the south (Sirri A, Sirri C, Sirri D and Sirri E fields).

     

8.

CONTROLS ON THE DISTRIBUTION OF NUMMULITE FACIES: A CASE STUDY FROM THE LATE YPRESIAN EL GARIA FORMATION (KESRA PLATEAU, CENTRAL TUNISIA)     

S. Jorry  E. Davaud  B. Caline 《Journal of Petroleum Geology》2003,26(3):283-306

Eocene nummulite deposits along the southern Tethys margin locally constitute important hydrocarbon reservoir rocks. In order to understand the heterogeneity of these complex reservoirs, we have carried out a detailed field study of the nummulite limestones which crop out at the Kesra Plateau in Central Tunisia. The main contributions of this paper can be summarised as follows:

• (1) 

  Various species of Nummulites and planktonic foraminifera were identified in late Ypresian carbonates in the Kesra area and provided accurate biostratigraphic ages. Nummulitic limestones occur in the Chouabine and El Garia Formations representing deposition over a period of about 2Ma.

       
  
  

9.

GEOLOGICAL INTERPRETATION OF WELL TEST ANALYSIS: A CASE STUDY FROM A FLUVIAL RESERVOIR IN THE GULF OF THAILAND     

S. Y. Zheng  P. W. M. Corbett  A. Emery 《Journal of Petroleum Geology》2003,26(1):49-64

One problem with the inversion of transient well test data is that it can yield a non-unique solution. The uncertainty resulting from this type of approach can only be resolved by considering information from another source such as geology. Geological information will help to define the interpretation model which will ensure the correct analysis of the well test data. The results of well test analyses are of little value to reservoir characterisation and modelling unless they can be explained from a geological point of view. This last step is what we refer to here as geological interpretation. Other sources of information which can help with well test analyses come from seismic surveys and petrophysics. Modern well test interpretation therefore consists of two major steps: analysis of the well test data; and interpretation of the results. In detail, this should include the following:

• (1) 

  definition of an interpretation model — this requires the integration of geological, seismic and petrophysical data with transient pressure data

       
  
  

10.

ANALYSIS OF RESERVES DISCOVERED IN PETROLEUM EXPLORATION     

D. G. Quirk  R. Ruthrauff 《Journal of Petroleum Geology》2006,29(2):125-146

Mathematical theory and empirical data show that discovery sizes from mature plays have lognormal distributions. This allows a simple transformation to be used that converts lognormal trends to straight lines from which valuable statistical data on exploration potential is derived.
After correcting for the unreliable nature of data from non-commercial accumulations and then discounting the extreme high ends and low ends (P1), discovery size distributions from a variety of mature plays outside the Middle East show certain common properties that help constrain reserves ranges in individual prospects and new play fairways. These are:

• •

  P99 is 0.3MM brl or less in non-DHI oil plays and 4BCF or less in gas plays at normal depths;

       
  
  

11.

DETERMINATION OF FAULT SLIP COMPONENTS USING SUBSURFACE STRUCTURAL CONTOURS: METHODS AND EXAMPLES     

S-S. Xu  L. G. Velasquillo-Martinez  J. M. Grajales-Nishimura  G. Murillo-Muñetón  J. García-Hernandez  A. F. Nieto-Samaniego 《Journal of Petroleum Geology》2004,27(3):277-298

Problems with measuring fault slip in the subsurface can sometimes be overcome by using subsurface structural contour maps constructed from well logs and seismic information. These maps are useful for estimating fault slip since fault motion commonly causes the dislocation of structural contours. The dislocation of a contour is defined here as the distance in the direction of fault strike between two contours which have the same value on both sides of a fault. This dislocation can be estimated for tilted beds and folded beds as follows:

• (i) 

  If a dip-slip fault offsets a tilted bed, the dislocation (S_c) of contours can be estimated from the vertical component (S_v) of the fault slip and the dip (β) of the bedding according to the following relationship: S_c= S_v/tan β. Since S_c and β can be measured from a contour map, the vertical component of fault slip can be obtained from this equation.

  If a strike-slip fault offsets a tilted bed, the dislocation (S_cs) of contours is equal to the strike-slip of the fault (S_c), that is, S_cs= S_s.

       
  
  

12.

Technical and Economical Analysis of Hydrogen Sulfide Removal from the Recycled Hydrogen in a Diesel Hydrodesulfurization Plant     

《Petroleum Science and Technology》2013,31(1-2):73-85

Abstract

Hydrodesulfurization (HDS) is a catalytic process used to remove sulfur compounds, which leads to very low sulfur concentrations. HDS turns more complicated and severe according to the feedstock boiling range, since sulfur compounds present in light cuts, normally sulfides and mercaptanes, are easy to remove, and sulfoaromatic compounds, specially polycyclics, are the more refractive ones (Speight, J. G. (1981 Speight, J. G. 1981. The Desulfurization of Heavy Oils and Residua Chemical Industries 4. , 2nd ed. Marcel Dekker Inc.  [Google Scholar]). The Desulfurization of Heavy Oils and Residua. 2nd ed. Marcel Dekker, Inc.: Chemical Industries 4.) The hydrogen sulfide (H₂S) produced in the HDS has an inhibiting effect on the same reaction, as it has been widely observed (McCulloch, D. C. (1983 McCulloch, D. C. 1983. Applied Ind. Catal., I: 69 [Google Scholar]). Applied Ind Catal. I:69; National Petroleum Refining Association (NPRA). (1993 National Petroleum Refining Association, NPRA. 1993. Questions & Answers 99 [Google Scholar]). Questions & Answers, 99; Leglise, J., Van Gestel, J., Duchet, J. C. (1994 Leglise, J., Van Gestel, J. and Duchet, J. C. Symposium on advances in hydrotreating catalysts presented before the division of petroleum chemistry Inc. 208th National Meeting. pp.pp. 533Washington, D.C.: American Chemical Society.  [Google Scholar]). Symposium on Advances in Hydrotreating Catalysts Presented before the Division of Petroleum Chemistry Inc. In: 208th National Meeting American Chemical Society. Washington D.C. p. 533). This effect is well known even at relatively low H₂S concentrations (2 mol%) for commercial operation conditions (Leglise, J., Van Gestel, J., Duchet, J. C. (1994 Leglise, J., Van Gestel, J. and Duchet, J. C. Symposium on advances in hydrotreating catalysts presented before the division of petroleum chemistry Inc. 208th National Meeting. pp.pp. 533Washington, D.C.: American Chemical Society.  [Google Scholar]). Symposium on Advances in Hydrotreating Catalysts Presented before the Division of Petroleum Chemistry Inc. In: 208th National Meeting American Chemical Society. Washington D.C. p. 533). Due to this, the H₂S removal from the recycled hydrogen to the reactor is mandatory in order to increase the desulfurization levels or to increase the processing capacity of an HDS plant. There are many options to low the H₂S concentration in the H₂ loop (Cooper, A., Stanislaus, A., Hannerup, P. N. (June 1993 Cooper, A., Stanislaus, A. and Hannerup, P. N. 1993. Hyd. Process., June: 84 June [Google Scholar]). Hyd Process 84; Johnson, A. D. (1983 Johnson, A. D. 1983. Oil and Gas J., 10: 78 [Google Scholar]). Oil and Gas J 10:78; Nash, R. M. (1989 Nash, R. M. 1989. Oil and Gas J., 13: 47 [Google Scholar]). Oil and Gas J 13:47; Suchanek, A. J., Dave, D., Gupta, A., Van Stralen, H., Karlsson, K. (1993 Suchanek, A. J., Dave, D., Gupta, A., Van Stralen, H. and Karlsson, K. NPRA Annual Meeting. AM-93-24 [Google Scholar]). In: NPRA Annual Meeting AM-93-24; Tippett, T., Knudsen, K. G. (1999 Tippett, T. and Knudsen, K. G. NPRA Annual Meeting. San Antonio, TX. AM-99-06 [Google Scholar]). In: NPRA Annual Meeting. San Antonio, TX. 1999 NPRA Annual Meeting, San Antonio, TX, AM-99-06.), which are from a simple purge adjustment for light naphtha HDS to a full treatment of the H₂ stream for middle distillate HDS, where the H₂S concentration can reach levels of 10 mol% (National Petroleum Refining Association (NPRA). (1993 National Petroleum Refining Association, NPRA. 1993. Questions & Answers 99 [Google Scholar]). Questions & Answers, 99). This work presents the economical analysis of the introduction of an Amine Treating Unit in an HDS plant in operation to remove H₂S from the H₂ stream recycled to the reactor.     

13.

High-temperature adsorption of C7-C13 n-paraffins on MgNaA zeolite     

Yu. P. Ryazantsev  V. V. Kurnoskina 《Chemistry and Technology of Fuels and Oils》1976,12(5):346-349

     

14.

INTERACTIONS BETWEEN TECTONIC ACTIVITY AND EUSTATIC SEA-LEVEL CHANGES IN THE PINDOSAND MESOHELLENIC BASINS, NW GREECE: BASIN EVOLUTION AND HYDROCARBON POTENTIAL     

P. Avramidis  A. Zelilidis  I. Vakalas  N. Kontopoulos 《Journal of Petroleum Geology》2002,25(1):53-82

This paper investigates the sedimentological response of the Tertiary Pindos and Mesohellenic Basins to localized tectonic and eustatic sea-level changes in a submarine setting dominated by turbidite deposition. Five composite stratigraphic cross-sections were compiled from field data, three in the Pindos Basin and two in the Mesohellenic Basin; 45 samples were dated by means of nannofossil bio stratigraphy. On the basis of these field studies, we relate observed changes in depositional environment to eustatic sea-level changes and to activity on local thrusts. Between the early Eocene and the late Miocene, tectonically-driven subsidence in both basins was generally more significant than eustatic variations in controlling depositional patterns. However, depositional conditions can be related to eustatic changes at four specific times:

• (i)

  late Eocene submarine fans and deltaic or fan-delta deposits in the Mesohellenic Basin can be related to a sea-level rise (NP17) and subsequent fall (NP18-19), respectively;

       
  
  

15.

英文摘要     

《石油天然气学报》2010,32(4):I0001-I0007

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16.

英文摘要     

《石油化工设计》2009,26(4)

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17.

英文文摘     

《录井工程》2009,20(4):74-78

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18.

英文摘要     

《石油化工设备技术》2010,31(2):I0001-I0004

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19.

Effect of temperature and concentration of solutions on the position of <Superscript>13</Superscript>C NMR signals for fractions of saturated hydrocarbons forming urea adducts     

M. B. Smirnov  V. A. Melikhov  N. A. Vanyukova 《Petroleum Chemistry》2007,47(1):23-31

An empirical equation was proposed for calculating the chemical shifts of ¹³C NMR signals from monomethylated alkanes and mono-n-alkyl-substituted cyclopentanes and cyclohexanes in the spectra of isoparaffin and naphthene fractions that form adducts with urea, depending on the analyte concentration in deuterochloroform C and the spectrum recording temperature T _rec. Deviations of the calculated chemical shifts from the measured values did not exceed 5 × 10^?3 ppm while varying T _rec from 303 to 323 K and C from 200 to 600 mg/ml. It was shown that such an accuracy is sufficient for the unequivocal identification of components by means of ¹³C NMR technique; ignoring this dependence leads to errors in signal assignment in the spectra of petroleum fractions. The use of the chemical shift of certain signals as internal standards for determination of T _rec and C was proposed. It was assumed that numerical values of the temperature and concentration coefficients that describe the dependence of the chemical shift on T _rec and C would be useful for the ¹³C NMR detection of new groups of compounds in petroleum hydrocarbons.     

20.

英文摘要     

《石油化工设备技术》2010,31(1)

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ORIENTING CONVENTIONAL CORES FOR GEOLOGICAL PURPOSES: A REVIEW OF METHODS

A review of four simple techniques used to re-orient conventional cores back to theri in-situ position in presented. Cores can be oriented by:

• 1. 

  Cutting oriented. cores;
• 2. 

  Using dipmeters;
• 3. 

  Re-orienting in highly deviated holes;
• 4. 

  Using remanent palaeomagnetism.

The accuracy, costs and limitations of the methods are considered.     

FUZZY MODELLING AND THE PREDICTION OF POROSITY AND PERMEABILITY FROM THE COMPOSITIONAL AND TEXTURAL ATTRIBUTES OF SANDSTONE

A new method is presented here for predicting porosity and permeability from the compositional and textural characteristics of sandstones. The method employs fuzzy modelling which is a linguistic paradigm based on fuzzy logic, rooted in the theory of fuzzy sets. The essentials of fuzzy modelling are explained using an example in which porosity and permeability values of a sandstone are predicted from five compositional and textural attributes. Fuzzy modelling can be accomplished in five steps:

• (i) 

  Identification of input and output variables. In this paper, the inputs are five compositional and textural parameters, namely: relative amounts of ductile grains, rigid grains and detrital matrix, to gether with grain size, and the Trask sorting coefficient. The output is either porosity or permeability.
• (ii) 

  Fuzzy clustering of output values.
• (iii) 

  Formation of membership grades of input data.
• (iv) 

  Generation of fuzzy rules; and
• (v) 

  Prediction via fuzzy inference.

Compared to statistical modelling (i. e. multiple regression analysis), fuzzy modelling is not only assumption-free but is also tolerant of outliers. Fuzzy modelling is capable of making both linguistic and numeric predictions based on qualitative knowledge and/ or quantitative data. Thus, fuzzy modelling is not only appropriate for the problem discussed here, but is also desirable for many geological problems characterized by non-numerical knowledge and imprecise information.     

GEOCHEMISTRY OF CRUDE OIL SAMPLES FROM THE IRANIAN SECTOR OF THE PERSIAN GULF

High-resolution (biomarker) geochemistry combined with other geochemical data has been used to investigate the genetic relationships of 14 crude oil samples from the Iranian sector of the Persian Gulf, and to provide information on the lithologies, palaeo-depositional environments and probable ages of the respective source rocks. Oil samples from the Resalat, Salman, Sirri A, Sirri C, Sirri D and Sirri E fields in the SE of the Gulf, and the Foroozan, Bahregansar, Hendijan, Abouzar, Doroud and Nowrouz fields in the NW of the Gulf were investigated.
Results indicate that the studied oils belong to three genetic groups:

• (i)  

  Group 1 oils (Resalat and Salman fields) were sourced from Jurassic or older, shaly source rocks deposited in a relatively oxic environment;
• (ii)  

  Group 2 oils (Nowrouz, Doroud and Foroozan oilfields) originated from Jurassic or older carbonate-rich source rocks deposited in an anoxic environment;
• (iii)  

  Group 3 oils, which, according to biomarker parameters, were probably sourced from Middle Cretaceous calcareous shales. Two subgroups are recognised: subgroup 3A oils were sampled from oilfields located in the NW of the Gulf (Hendijan, Bahregansar and Abouzar), and subgroup 3B oils came from the south (Sirri A, Sirri C, Sirri D and Sirri E fields).

     

CONTROLS ON THE DISTRIBUTION OF NUMMULITE FACIES: A CASE STUDY FROM THE LATE YPRESIAN EL GARIA FORMATION (KESRA PLATEAU, CENTRAL TUNISIA)

Eocene nummulite deposits along the southern Tethys margin locally constitute important hydrocarbon reservoir rocks. In order to understand the heterogeneity of these complex reservoirs, we have carried out a detailed field study of the nummulite limestones which crop out at the Kesra Plateau in Central Tunisia. The main contributions of this paper can be summarised as follows:

• (1) 

  Various species of Nummulites and planktonic foraminifera were identified in late Ypresian carbonates in the Kesra area and provided accurate biostratigraphic ages. Nummulitic limestones occur in the Chouabine and El Garia Formations representing deposition over a period of about 2Ma.

       
  
  

GEOLOGICAL INTERPRETATION OF WELL TEST ANALYSIS: A CASE STUDY FROM A FLUVIAL RESERVOIR IN THE GULF OF THAILAND

One problem with the inversion of transient well test data is that it can yield a non-unique solution. The uncertainty resulting from this type of approach can only be resolved by considering information from another source such as geology. Geological information will help to define the interpretation model which will ensure the correct analysis of the well test data. The results of well test analyses are of little value to reservoir characterisation and modelling unless they can be explained from a geological point of view. This last step is what we refer to here as geological interpretation. Other sources of information which can help with well test analyses come from seismic surveys and petrophysics. Modern well test interpretation therefore consists of two major steps: analysis of the well test data; and interpretation of the results. In detail, this should include the following:

• (1) 

  definition of an interpretation model — this requires the integration of geological, seismic and petrophysical data with transient pressure data

       
  
  

ANALYSIS OF RESERVES DISCOVERED IN PETROLEUM EXPLORATION

Mathematical theory and empirical data show that discovery sizes from mature plays have lognormal distributions. This allows a simple transformation to be used that converts lognormal trends to straight lines from which valuable statistical data on exploration potential is derived.
After correcting for the unreliable nature of data from non-commercial accumulations and then discounting the extreme high ends and low ends (P1), discovery size distributions from a variety of mature plays outside the Middle East show certain common properties that help constrain reserves ranges in individual prospects and new play fairways. These are:

• •

  P99 is 0.3MM brl or less in non-DHI oil plays and 4BCF or less in gas plays at normal depths;

       
  
  

DETERMINATION OF FAULT SLIP COMPONENTS USING SUBSURFACE STRUCTURAL CONTOURS: METHODS AND EXAMPLES

Problems with measuring fault slip in the subsurface can sometimes be overcome by using subsurface structural contour maps constructed from well logs and seismic information. These maps are useful for estimating fault slip since fault motion commonly causes the dislocation of structural contours. The dislocation of a contour is defined here as the distance in the direction of fault strike between two contours which have the same value on both sides of a fault. This dislocation can be estimated for tilted beds and folded beds as follows:

• (i) 

  If a dip-slip fault offsets a tilted bed, the dislocation (S_c) of contours can be estimated from the vertical component (S_v) of the fault slip and the dip (β) of the bedding according to the following relationship: S_c= S_v/tan β. Since S_c and β can be measured from a contour map, the vertical component of fault slip can be obtained from this equation.

  If a strike-slip fault offsets a tilted bed, the dislocation (S_cs) of contours is equal to the strike-slip of the fault (S_c), that is, S_cs= S_s.

       
  
  

Technical and Economical Analysis of Hydrogen Sulfide Removal from the Recycled Hydrogen in a Diesel Hydrodesulfurization Plant

Abstract

Hydrodesulfurization (HDS) is a catalytic process used to remove sulfur compounds, which leads to very low sulfur concentrations. HDS turns more complicated and severe according to the feedstock boiling range, since sulfur compounds present in light cuts, normally sulfides and mercaptanes, are easy to remove, and sulfoaromatic compounds, specially polycyclics, are the more refractive ones (Speight, J. G. (1981 Speight, J. G. 1981. The Desulfurization of Heavy Oils and Residua Chemical Industries 4. , 2nd ed. Marcel Dekker Inc.  [Google Scholar]). The Desulfurization of Heavy Oils and Residua. 2nd ed. Marcel Dekker, Inc.: Chemical Industries 4.) The hydrogen sulfide (H₂S) produced in the HDS has an inhibiting effect on the same reaction, as it has been widely observed (McCulloch, D. C. (1983 McCulloch, D. C. 1983. Applied Ind. Catal., I: 69 [Google Scholar]). Applied Ind Catal. I:69; National Petroleum Refining Association (NPRA). (1993 National Petroleum Refining Association, NPRA. 1993. Questions & Answers 99 [Google Scholar]). Questions & Answers, 99; Leglise, J., Van Gestel, J., Duchet, J. C. (1994 Leglise, J., Van Gestel, J. and Duchet, J. C. Symposium on advances in hydrotreating catalysts presented before the division of petroleum chemistry Inc. 208th National Meeting. pp.pp. 533Washington, D.C.: American Chemical Society.  [Google Scholar]). Symposium on Advances in Hydrotreating Catalysts Presented before the Division of Petroleum Chemistry Inc. In: 208th National Meeting American Chemical Society. Washington D.C. p. 533). This effect is well known even at relatively low H₂S concentrations (2 mol%) for commercial operation conditions (Leglise, J., Van Gestel, J., Duchet, J. C. (1994 Leglise, J., Van Gestel, J. and Duchet, J. C. Symposium on advances in hydrotreating catalysts presented before the division of petroleum chemistry Inc. 208th National Meeting. pp.pp. 533Washington, D.C.: American Chemical Society.  [Google Scholar]). Symposium on Advances in Hydrotreating Catalysts Presented before the Division of Petroleum Chemistry Inc. In: 208th National Meeting American Chemical Society. Washington D.C. p. 533). Due to this, the H₂S removal from the recycled hydrogen to the reactor is mandatory in order to increase the desulfurization levels or to increase the processing capacity of an HDS plant. There are many options to low the H₂S concentration in the H₂ loop (Cooper, A., Stanislaus, A., Hannerup, P. N. (June 1993 Cooper, A., Stanislaus, A. and Hannerup, P. N. 1993. Hyd. Process., June: 84 June [Google Scholar]). Hyd Process 84; Johnson, A. D. (1983 Johnson, A. D. 1983. Oil and Gas J., 10: 78 [Google Scholar]). Oil and Gas J 10:78; Nash, R. M. (1989 Nash, R. M. 1989. Oil and Gas J., 13: 47 [Google Scholar]). Oil and Gas J 13:47; Suchanek, A. J., Dave, D., Gupta, A., Van Stralen, H., Karlsson, K. (1993 Suchanek, A. J., Dave, D., Gupta, A., Van Stralen, H. and Karlsson, K. NPRA Annual Meeting. AM-93-24 [Google Scholar]). In: NPRA Annual Meeting AM-93-24; Tippett, T., Knudsen, K. G. (1999 Tippett, T. and Knudsen, K. G. NPRA Annual Meeting. San Antonio, TX. AM-99-06 [Google Scholar]). In: NPRA Annual Meeting. San Antonio, TX. 1999 NPRA Annual Meeting, San Antonio, TX, AM-99-06.), which are from a simple purge adjustment for light naphtha HDS to a full treatment of the H₂ stream for middle distillate HDS, where the H₂S concentration can reach levels of 10 mol% (National Petroleum Refining Association (NPRA). (1993 National Petroleum Refining Association, NPRA. 1993. Questions & Answers 99 [Google Scholar]). Questions & Answers, 99). This work presents the economical analysis of the introduction of an Amine Treating Unit in an HDS plant in operation to remove H₂S from the H₂ stream recycled to the reactor.     

INTERACTIONS BETWEEN TECTONIC ACTIVITY AND EUSTATIC SEA-LEVEL CHANGES IN THE PINDOSAND MESOHELLENIC BASINS, NW GREECE: BASIN EVOLUTION AND HYDROCARBON POTENTIAL

This paper investigates the sedimentological response of the Tertiary Pindos and Mesohellenic Basins to localized tectonic and eustatic sea-level changes in a submarine setting dominated by turbidite deposition. Five composite stratigraphic cross-sections were compiled from field data, three in the Pindos Basin and two in the Mesohellenic Basin; 45 samples were dated by means of nannofossil bio stratigraphy. On the basis of these field studies, we relate observed changes in depositional environment to eustatic sea-level changes and to activity on local thrusts. Between the early Eocene and the late Miocene, tectonically-driven subsidence in both basins was generally more significant than eustatic variations in controlling depositional patterns. However, depositional conditions can be related to eustatic changes at four specific times:

• (i)

  late Eocene submarine fans and deltaic or fan-delta deposits in the Mesohellenic Basin can be related to a sea-level rise (NP17) and subsequent fall (NP18-19), respectively;

       
  
  

英文摘要

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英文摘要

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英文文摘

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英文摘要

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Effect of temperature and concentration of solutions on the position of <Superscript>13</Superscript>C NMR signals for fractions of saturated hydrocarbons forming urea adducts

An empirical equation was proposed for calculating the chemical shifts of ¹³C NMR signals from monomethylated alkanes and mono-n-alkyl-substituted cyclopentanes and cyclohexanes in the spectra of isoparaffin and naphthene fractions that form adducts with urea, depending on the analyte concentration in deuterochloroform C and the spectrum recording temperature T _rec. Deviations of the calculated chemical shifts from the measured values did not exceed 5 × 10^?3 ppm while varying T _rec from 303 to 323 K and C from 200 to 600 mg/ml. It was shown that such an accuracy is sufficient for the unequivocal identification of components by means of ¹³C NMR technique; ignoring this dependence leads to errors in signal assignment in the spectra of petroleum fractions. The use of the chemical shift of certain signals as internal standards for determination of T _rec and C was proposed. It was assumed that numerical values of the temperature and concentration coefficients that describe the dependence of the chemical shift on T _rec and C would be useful for the ¹³C NMR detection of new groups of compounds in petroleum hydrocarbons.     

英文摘要

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