Atlas Geoquimico 2010

7/27/2019 Atlas Geoquimico 2010

1/182

D

E

C

E

M

B

E

R

December 2010Volume 14, Special Edition

INTRODUCTION ...................................................................................................................................................................................................................................................... 1METHODOLOGY ...................................................................................................................................................................................................................................................... 3CAGUN - P UTUMAYO BASIN.............................................................................................................................................................................................................................. 5CATATUMBO BASIN................................................................................................................................................................................................................................................ 20CAUCA-PATIABASIN............................................................................................................................................................................................................................................... 31CESAR - RANCHERABASIN................................................................................................................................................................................................................................ 39CHOC BASIN........................................................................................................................................................................................................................................................... 47EASTERN CORDILLERABASIN........................................................................................................................................................................................................................... 53EASTERN LLANOS BASIN..................................................................................................................................................................................................................................... 61GUAJIRABASIN........................................................................................................................................................................................................................................................ 77GUAJIRAOFFSHORE BASIN................................................................................................................................................................................................................................. 83LOS CAYOS BASIN ................................................................................................................................................................................................................................................ 89LOWER MAGDALENAVALLEY BASIN.............................................................................................................................................................................................................. 93MIDDLE MAGDALENAVALLEY BASIN............................................................................................................................................................................................................. 105SIN OFFSHORE BASIN......................................................................................................................................................................................................................................... 118SIN - SAN JACINTO BASIN.................................................................................................................................................................................................................................. 123TUMACO BASIN........................................................................................................................................................................................................................................................ 132TUMACO OFFSHORE BASIN................................................................................................................................................................................................................................. 137UPPER MAGDALENAVALLEY BASIN................................................................................................................................................................................................................ 141URAB BASIN............................................................................................................................................................................................................................................................ 157REFERENCES............................................................................................................................................................................................................................................................ 162APPENDIX - ANH ORGANIC GEOCHEMISTRY DATABASE DATASOURCES ......................................................................................................................................... 164

Organic Geochemistry Atlas of ColombiaSecond Edition

4

1 1 1 2 2 2 2 2By: Roberto Aguilera , Vctor Sotelo, Carla Burgos, Carolynna Arce , Clemencia Gmez, Jairo Mojica , Hardany Castillo, Diana Jimnez and Jos Osorno1 2RAGEOLOGIAE.U . and ANH

2

0

0 50 100

100

50

0100

50

0

%NSO%AROMATIC

%SATURATE

3 70 3 90 4 10 4 30 4 50 4 70 4 90 5 10 5 30 5 50

Tmax (oC)

0

200

400

600

HydrogenIndex(mgHC/gTOC)

III

III

1.35% Ro

0.5

%

Ro

Immature Mature Overmature

1

2


2/182

Published by:UNIVERSIDAD NACIONAL DE COLOMBIAFacultad de CienciasDepartamento de Geociencias

ESRJ publishes the results from technical and scientificresearch on various disciplines of Earth Sciences and itsinteractions with several engineering applications.Works will only be considered if not previously publishedanywhere else. Manuscripts must contain informationderived from scientific research projects or technicaldevelopments. The ideas expressed by publishing in ESRJare the sole responsibility of the authors. The contents ofthis journal can be reproduced provided appr opiate citationis mentioned.

Mail address, suscription and submissionof manuscripts:Universidad Nacional de ColombiaDepartamento de GeocienciasEdificio Manuel Anczar, of. 326Phone: +57-1 3165000 Ext. 16514 16539Fax: + 57-1 3165390e-mail: [email protected]

URL:http://www.geociencias.unal.edu.co/ESRJ.htm

Suscription ratesColombia: $ 30000Abroad: US$20 included mail service.Price of this issue: $15000 or US$10

Earth Sciences Research Journal is published biannuallyin December and June.

Date and place of edition:December 2010,Bogot - Colombia

Papers published in Earth Sciences Research Journal arecovered and indexed in the following Bibliographic Index:

EBSCO, Chemical Abstracts Service CAS, GeoRef,Scielo, Publindex, Latindex, British Library, ISINET,Intute, Ulrich.

Printed and diagramed by:Universidad Nacional de ColombiaEDITORIAL UNIVERSIDAD NACIONALDE COLOMBIABogot, D.C., Colombia, 2010

CHIEF EDITORLuis A. Montes V.Departamento de GeocienciasEdificio Manuel Anczar, of. 326Ciudad UniversitariaBogot, Colombia.

EDITORIAL COMMITTEE

Alexander [email protected] Antonio Nario

Carlos [email protected] Nacional de Colombia

Gabriel [email protected]

Lluis [email protected] Politcnica de Catalua

SCIENTIFIC COMMITTEE

Frank [email protected] Venezolana de Investigaciones SismolgicasCaracas - Venezuela

Carlos A. [email protected] Nacional de Hidrocarburos - ANHBogot - Colombia

Peggy [email protected] of BerkeleyCalifornia - USA

Mario Ordz [email protected] Nacional Autnoma de MxicoCiudad de Mxico-Mxico

Arantza [email protected] del EbroBarcelona Espaa

EARTH SCIENCESRESEARCH JOURNAL

Manuscript SubmissionManuscriptssubmitted to ESRJwill only beconsideredif theyhave not been or not will bereproduced in thesame extension and form ina different journal. Material as figures,tables,photos, etc.which will bereproduced in papersrequiresthe permission of originalauthors.Contributions falling into the followingcategorieswill be considered for

publication: RegularPapers: Regular papersconstitutemost of the workspublished inESRJand

contain original information (e.g. that has not been published, and is not beingconsidered for publicationelsewhere). Therearenolimitations to thelength of regular

papers, but weencourageauthorsto expresstheir viewsin aconcisemanner. From ourexperiencewehavefoundthat the shorter thepaper, thebetter they arereceived.

Brief Contributions:Tobeconsidered asa Brief Contribution,your manuscript mustcontain original informationthat may bemore limited in length andscope than aRegular Paper.Sometimesauthorswish to concisely sharetheir research and may do sothroughaBrief Contribution, which should belimited to six (6) pagesor less, includinganyfigures.

Comments, Praise, and Replies:Sometimesdifferencesin opinionsand viewsarisefrom published researchand theEarth Sciencescommunity maybenefit from opendiscussion. Sometimesan author'soutstanding contributionmay bepublicly praised,asa way to acknowledgethegood work. Commentson and Praisesto contributionsaswell astheir Replies, should not exceedtwo (2) pagesinlength.

Translationsof Articles: There are many papers (especially classic papers) thatrepresent momentousfactsin theEarth Scienceshistory. Someother important articlesremain unknown to the Spanish-Speakingor English- Speaking sciencecommunities

becausethesearticlesare published inforeignlanguages. Translationsof articlesmaybe submitted to ESRJprovided that written authorization of original publishers isobtained.

Withthe exceptionof Comments, Praises, and Replies, all submissionsmust contain thefollowing parts:

TITLE. NAME(S) OF AUTHOR(S). Pleaseunderlinethenameof thecorrespondingauthor. ABSTRACT. Shouldnot exceed 300words(English). Alist of keywordsmust appear

followingtheabstract, and INTRODUCTION. DATA. METHOD. RESULTS. DISCUSION. CONCLUSIONS. REFERENCES. ACKNOWLEDGEMENTS (Optional) AUTHORS CONTACTINFORMATION. Please providecontact information that

includes: Affiliation, e-mail, physical address, telephone, and fax numbers. APPENDIX(If any).

If amanuscript fallsi n theBrief Contribution category,thefollowing sectionsmay bejoined:

DATAANDMETHOD. DISCUSIONANDCONCLUSIONS.

All submissionswill undergo peer-reviewby expertsinthesubject areabeingconsidered.Usually two reviewersareassigned; oneof them may bealocal scientist. Thenamesof theauthorsarekept in confidentiality.

Potential Reviewersof yourManuscript

ESRJmaintainsa databaseof reviewers and expertsin variousdisciplinesof EarthSciences. To speedup theprocessof review, however, werequest that the author suggestsat least four (4) potential reviewersfor their work. The list of potential reviewersshouldcontain full contact information and must beincluded along with thesubmission forconsiderationin ESRJ. Suggested reviewersmust fulfill thefollowingrequisites:

MS or Ph.Dacademicdegreeinadisciplinerelated to the work under consideration. Scientificproduction (publications) duringthelast two years. Preferablyaffiliated with aninstitution that isdifferent from that of theauthor.Toguaranteehigh standardsandethicsduring thereview process, theEditorial Board of

ESRJreserves theright of sendingmanuscriptsto thosereviewers whom weconsiderappropriate.We encourage submission of manuscriptsvia e-mail (MSWord or PDF formatsare

preferred). Optionally,authors may submit their worksas hard copies. In thiscase werequest three(3) copiesof themanuscript. After thereviewingprocessiscompleted andthe

paper isaccepted for publication, adigital form of themanuscript will berequested forediting and final minor modificationsprior to publishing.

Guidelinesfor preparation of yourmanuscript

Manuscriptsmust bewritten entirely in English,and must bespell-checked usingaword processor. Pleasemakesurethat structureand grammar are appropriate. Keepinmind that ESRJisa wide-scopejournal andyour articlemay bereadby scientistsfrom

INSTRUCTIONS FOR AUTHORS

other disciplines. After reviewing process is completed, ESRJstaff will produceanaccurateSpanish version of theabstract. Both abstracts(English and Spanish versions)arepublished.

Prepareyour manuscript usingletter-sizepages(216 mm 279mm).Pleaseuse size12TimesNewRoman or Arial fonts, with doublelinespacing.

Figures, Tables,and Equations

Limit figuresto nomore than five(5) shadesof grayscale. If you useelementssuchaslines, linestripes, dots, or specificsymbols, makesure they will beeasily distinguishedwhenreduced for publication.

Pleasealwaysincludegeographiccoordinatesand/or scalein maps. Thesizesof lettersare very important. Try to usethesamesize text throughout afigure.

Figureswill bereduced insize for publication. UseTimesRoman or Arial fonts. Avoidusing light text on dark background.

Try to createfiguresthat areas closeaspossibleto thesizetheywill appear in theprinted versionof ESRJ.

Try no to usetoo much black in your figures. For example,somejournalshavefoundthat record sectionswithtoo much black reproducepoorly.

Werequiretheuseof S.I. physical units(m, kg, s). Every figure must have a number and a figure caption. The latter describes,as

completely aspossible, thecontent of thegraphic. Pleasemakesurethat all symbolsandabbreviationsarefully explained.

Pleasebeaware that becausewe area self-financed journal, at present, high costs donot allowusto publishcolor figures.All figureswill bepublishedinblackand whiteorgray scale. Pleaseprepareyour figuresaccordingly.

All tablesshould benumbered and must haveatitle. Pleasenumber all equationsat theright.

Format forReferencesReferencesshouldbearranged alphabetically by author and should follow theformat thatappearsbelow.

Referenceto apaper publishedina Journal followingVancouver Style:

Print Documents, Books.Note:Onlythefirst wordof in thetitle of abook or conferenceshouldbecapitalised, except for proper nounsor acronyms.Capitalisethe"v"i n Volumefor abook title.

Standard format :#.Author/editor AA. Title: subtitle. Edition(if not thefirst). Vol.(if amultivolume work). Place of publication: Publisher; Year. p. page number(s) (ifappropriate).

Partsof a Book. Note:Theseexamplesarefor chaptersor partsof edited worksinwhichthechaptersor parts haveindividual titleand author/s, but areincluded in collectionsortextbooksedited by others. If theeditorsof awork arealso theauthorsof all of theincludedchaptersthen it should becited asa wholebook using theexamplesgiven above(Books).Capitaliseonly thefirst word of apaper or book chapter.

Standard format:#. Author of Part, AA. Titleof chapter or part. In: Editor A, Editor B,editors. Title: subtitleof Book. Edition(if not thefirs t). Placeof publication: Publisher;Year. p. pagenumber s.

Journal Articles.Note: Capitaliseonlythe first word of an articletitle, except for propernounsor acronyms. List thefirst six authorsfollowed byet al. Thetitlesof journalsshould

beabbreviatedasthey appear in theMEDLINE JournalsDatabase. Volume, issueandpagenumbersaregiven but not labeled. To indicateapagerangeuse 123-9, 126-34or 111-222.If yourefer toonly onepage, useonly 111.

Standard format:#. Author of articleAA, Author of article BB, Author of articleCC. Titleof article. AbbreviatedTitleof Journal.year; vol(issue):pagenumber(s).

ElectronicDocuments. Note:When you citean electronicsourcetry to describeit in thesameway you would describeasimilar printed publication. If possible, givesufficientinformation for your readers to retrievethe sourcethemselves. If only thefirst pagenumber isgiven, aplus sign indicatesfollowing pages, eg. 26+. If pagenumbersarenotgiven, useparagraph or other sectionnumbersif you need to bespecific. An electronicsourcemaynot always contain clear author or publisher details. Theaccessinformationwill usuallybejust theURLof the source. Aswell asapublication/revision date(if thereisone), thedatecitedisi ncluded sinceanelectronicsourcemay changebetween thetimeyouciteit and thetimeit is accessed byareader.

E-Books. Standard format: #. Author A, Author B. Titleof e-book[format]. Place:Publisher; Dateof original publication [cited year abbreviatedmonth day]. Availablefrom:Source. URL.

E-Journals. Standard format: #. Author A, Author B.Titleof article. AbbreviatedTitleof Journal [format]. year [cited year abbreviated month day];vol(no):pagenumbers[estimated if necessary]. Availablefrom: DatabaseName(if appropriate). URL.

Internet Documents.Standard format:#. Author A, Author B. Document title. Webpagename[format]. Source/productioninformation; Dateof internet publication [citedyearmonth day]. Availablefrom: URL.

Non-Book Formats. Standard format:#. Person AA, Responsibility (if appropriate).Title: subtitle[format]. Special credits (if appropriate). Placeof publication: Publisher;Year.


3/182

Earth Sciences Research Journal Special Edition

ORGANIC GEOCHEMISTRY ATLAS OF COLOMBIASecond Edition

Roberto C. AguileraRA GEOLOGIA E.U.

Vctor A. SoteloRA GEOLOGIA E.U.

Carla A. Burgos

RA GEOLOGIA E.U.

Carolynna ArceAgencia Nacional de Hidrocarburos

Clemencia GmezAgencia Nacional de Hidrocarburos

Jairo Mojica

Agencia Nacional de Hidrocarburos

Hardany CastilloAgencia Nacional de Hidrocarburos

Diana JimnezAgencia Nacional de Hidrocarburos

Jos OsornoAgencia Nacional de Hidrocarburos

2010Earth Sciences Research Journal

Bogot


4/182


5/182

I

Letter of EditorScience is the knowledge of consequences and thedependence of one fact on anotherThomas Hobbes.

In a short time we are here again to offer you a new version ofthe Organic Geochemistry Atlas of Colombia. This effort issupported by the ANH, and extends the geochemicalknowledge disposed in the previous version to new basins, andupdated information up to 2009.

We hope that this document may be helpful to developers ofprojects of oil exploration and production, in a moment, whenthe exploration of new basins increases, and the oilassociated activities are extended to new business.

This Atlas will serve as a guide for the oil industry as well asresearch centers and academic institutions, who may consulton their pages the state of knowledge in this field in Colombia,and the need to continue carrying out projects of this nature.

Can these pages help to answer questions like: Has the trapreceived economic quantities of petroleum?. What types ofhydrocarbons are likely to be present (oil and/or gas and inwhat relative proportion)?. What are the oil or gas properties

(e.g., viscosity, API gravity, sulfur content, etc.)? Is reservoircompartmentalization an issue?

We let the answers to our readers, from whom we hope tohear their findings and if possible their contribution.

Luis MontesESRJ Chief Editor


6/182


7/182

ORGANIC GEOCHEMISTRY ATLAS OF COLOMBIA

TABLE OF CONTENTS

Introduction........................................................................................................................................ 1

Methodology........................................................................................................................................ 3

Cagun-Putumayo Basin.......................................................................................................................... 5

Catatumbo Basin.................................................................................................................................. 20

Cauca-Pata Basin................................................................................................................................. 31

Cesar-Ranchera Basin............................................................................................................................ 39

Choc Basin......................................................................................................................................... 47

Eastern Cordillera Basin.......................................................................................................................... 53

Eastern Llanos Basin............................................................................................................................. 61

Guajira Basin....................................................................................................................................... 77

Guajira Offshore Basin........................................................................................................................... 83

Los Cayos Basin.................................................................................................................................. 89

Lower Magdalena Valley Basin................................................................................................................. 93

Middle Magdalena Valley Basin................................................................................................................. 105

Sin Offshore Basin............................................................................................................................... 118

Sin-San Jacinto Basin........................................................................................................................... 123

Tumaco Basin...................................................................................................................................... 132

Tumaco Offshore Basin.......................................................................................................................... 137

Upper Magdalena Valley Basin................................................................................................................. 141

Urab Basin........................................................................................................................................ 157

References.......................................................................................................................................... 162

Appendix - ANH Organic Geochemistry Database Data Sources.............................................................................. 164


8/182


9/182


Introduction

This new and updated edition Organic Geochemistry Atlas ofColombia provides the explorationist with an overview of theexisting information on source rocks and crude oils in

Colombia. The data compiled in this work is updated to 2009,and is found in the Organic Geochemistry Database of theAgencia Nacional de Hidrocarburos (ANH).

This updated version of the database includes 10329 newsamples and 190836 associated geochemical data frompyrolysis, gas chromatography, liquid chromatography andsurface geochemistry reports, from works developed by theANH and exploration companies since 2003 to 2009. Thereferences of the data sources included in this database can

be found at the end of this volume.

This document is presented in a simple and graphical way toprovide a quick look of the state of the art of the colombianbasins, useful for newcomers or experts alike.

The Atlas is alphabetically organized, following thenomenclature and boundaries proposed by the ANH for theColombian sedimentary basins (Barrero et al. 2007).

Includes geochemical information, from 18 basins,corresponding to source rock analyses, organic mattercontent (%TOC), Rock-Eval pyrolysis, organic petrography,crude oil and extract analyses, liquid chromatography, gaschromatography, biomarkers and isotopes.

All the graphs and conclusions are drawn from the informationexisting in the organic geochemistry database ,and were usedfor source rocks quality assesments and to generate crude oiland gas characterization graphs of depositional, maturity and

quality parameters, along with quality and maturity maps ofsome of the main source rocks in Colombia.

Two new topics are present in this version of the Atlas, oneabout hydrocarbons origin from surface geochemistry dataand the other about petroleum systems from crude-rock

1

correlations.

These topics are treated in those basins in which surfacegeochemistry data, and where crude oil and rock extractsinformation, from reservoir and source rock units properlyidentified, exists.

Based on this information some insights on the source rocks,the origin of the hydrocarbons and petroleum systems foundin the Colombian basins are presented.

The Organic Geochemistry Atlas of Colombia is intended toassist E&P professionals interested in understanding the

origin and evolution of source rocks and crude/gasaccumulations present in any of the colombian basins, andadditionally as a guide on the future work that might beneeded to improve the knowledge and reduce the exploratoryrisk, especially in frontier areas of Colombia.

Therefore, this new version of the Organic Geochemistry Atlasof Colombia is expected to become a valuable tool forexploration and educational purposes as well.


10/182


11/182


3

Methodologyshowing the degree of preservation and processes affectingthe accumulations like mixing of different thermal maturityoils ( refreshing) and biodegradation.

- Source Rock Characterization: In order to show the qualityand maturity of the source rocks, crossplots based on PyrolysisRock-Eval and organic petrology data has been made. Theparameters used to estimate quality are organic mattercontent (%TOC),Hydrogen Index, Oxygen Index, andgenerative potential (S2 peak).The maturity parameters usedwere Pyrolysis Tmax in degrees Celsius, and vitrinitereflectance (%Ro). In the following tables are summarized thegeneral values used for interpretation of these data.

Organic matter generation potential:

Based on the organic geochemistry database of the ANH,compiled in 2010, an updated version of the OrganicGeochemistry Atlas of the Colombian basins has been made.

In order to provide an overview of the knowledge on crude oiland source rock characteristics in the colombian basins, thisvolume has been structured in chapters containinginformation on the following subjects, depending on theinformation available for each basin:

- Generalities: Including location, stratigraphy, structuralsections and highlights on the organic geochemistry dataavailable and used in the interpretations presented.

- Wells and Seeps: location map of wells and/or surfacelocations with geochemical information and oil and gas seepsin the basin.

- Crude Oil Quality: Crossplots of quality-related, bulkanalysis parameters like Ni/V, sulfur content, API gravity.These parameters give insights on the preservation ordegradation of the oils, their maturity (API gravity and sulfurcontent), depositional conditions (sulfur content and Ni/V)

and/or lithology of the source rocks (sulfur content).

- Depositional Environments: Crossplots of environment andorganic facies related biomarkers and ratios (Peters andMoldowan, 1993), like Oleanane Index, Homohopane Index,Pristane, Phytane, Pristane/nC17, Phytane/nC18, C27, C28and C29 steranes. These parameters provides information onthe type of organic matter terrestrial, marine or mixed(pristane/nC17 vs phytane/nC18, C27-C29 steranes, oleananeindex), bottom oxicity (homohopane index, pristane/nC17vs

phytane/nC18), depositional environments(homohopaneindex, oleanane index, pristane/phytane) and even age of thesource rocks (oleanane index).

- Chromatography: Typical examples of whole oilchromatograms and fragmentograms (m/z 191and m/z 217)

GenerationPotential

TOC (wt %)Rock-Eval S2 Peak (mg HC/ g

rock)

Poor 0 - 0.5 0 - 2.5

Fair 0.5 - 1 2.5 - 5

Good 1 - 2 5 - 10

Very Good 2 - 4 10 - 20

Excellent > 4 > 20

Kerogen Type Hydrogen Index (mg HC/ g TOC)

I > 600

II 300 - 600

III 50 -200

IV < 50


12/182


4

Methodology3. The symbol expressing the level of certainty.

The table below shows how the level of certainty isdetermined for a petroleum system (Magoon and Dow, 1994).

Based on these crossplots and maps some general conclusionson the crude oils , source rocks, gases and petroleum systems

are presented for each basin.

- Source Rock Quality and Maturity Maps: These maps weregenerated based on organic matter content (%TOC), HydrogenIndex and Tmax information available.

- Gas Characterization: Crossplots of gas molecularcomposition and stable carbon isotopes of methane, ethaneand propane were made in order to establish the origin andgeneration conditions of the gases found in the basins.

- Surface Geochemistry: Bernard and compositional plots ofsorbed gases in soil samples were made to help establishing itsorigin (thermogenic or biogenic) (Whiticar, 1990).

- Petroleum Systems (Crude - Rock Correlations): Based onthe crossplots used for depositional environmentsdetermination, a series of correlations of crude oil fromreservoirs and extracts from potential source rocks weremade in order to better establish petroleum systems,

following the nomenclature proposed by Magoon and Dow(1994), in which the name of a petroleum system containsthree parts:

1. The source rock in the pod of active source rock.2. The name of the reservoir rock that contains the largestvolume of petroleum.

Thermal Maturity Rock-Eval Tmax (C)Vitrinite Reflectance

Ro (%)

Immature < 435 0.2 - 0.6

Early Mature 435 - 445 0.6 - 0.65

Generation Peak 445 - 450 0.65 - 0.9

Late Mature 450 - 470 0.9 - 1.35

Overmature > 470 > 1.35

Level of Certainty Criteria Symbol

KnownA positive oil-source rock or gas -source

rock geochemical correlation(!)

HypotheticalIn the absence of a positive petroleum-source rock correlation, geochemical

evidence(.)

Speculative Geological or geophysical evidence (?)


13/182


CAGUN-PUTUMAYO BASIN

GeneralitiesWells and Seeps

Crude Oil Quality

Depositional EnvironmentsChromatographySource Rock Characterization

Source Rock Quality and Maturity MapsPetroleum Systems (Crude-Rock Correlations)


14/182



Generalities

6

The source rock geochemical informationinterpreted for the Cagun-Putumayo Basin

includes %TOC and Rock-Eval Pyrolysis data from2912 samples taken in 64 wells; additionally 335organic petrography samples from 56 wells wereinterpreted.

Crude oil and extracts information from 124 bulkanalysis samples, 403 liquid chromatographysamples, 330 gas chromatography samples,582biomarker samples and 90 isotopes samples werealso interpreted.

TD 9715ft

Sea level

SCHEMATIC CROSS SECTION

PUTUMAYO BASINNW SE

Paleozoic Jurassic

Paleogene

Upper Cretaceous

Color code according to the commission for the Geological Map of the World (2005)

Lower Cretaceous

Neogene

0

10000

ft

CAGUAN - PUTUMAYO BASINLOCATION AND BOUNDARIES

Pacific Ocean

Caribbean Sea

VENEZUELA

BRAZIL

PERU

ECUADOR

PANAMA

COLOMBIA

CaliNeiva

Villavicencio

24

SFR.

ECUADOR

PERU

PacOc

73 727475767778

2

1

0

1

2

3

4

2

1

0

1

2

3

4

73 727475767778

BOUNDARIES

Northwest: Eastern Cordillera Foothills fault system

East: Structural high, including the Serrana deChiribiquete (SCH)

South: Ecuadorian-Peruvian International border

Northeast: Sierra de la Macarena (SM)

San Josedel Guaviare

SCH

02

Paleozoic sedimentary rocks forming structural highs

Basement high

Florencia

SM

From Barrero et al., 2007


From Mojica et al., 2010

So urce Reser vo ir SealSandstone BasementShale


15/182



Wells and Seeps

The number of wells and/or surface locations

with geochemical information in the Cagun -Putumayo Basin is 116.

Oilseeps are located at the northern andwestern parts of the basin, as well as the oilfields

7

MOCOA

FLORENCIA

650000 700000 750000 800000 850000 900000 950000 1000000 1050000 1100000 1150000

300000

350000

400000

450000

500000

550000

600000

650000

700000

750000

800000

850000

0 50 100kms

Oil and gas fields

Wells with geochemical information

Oil seeps

Gas seeps

Undetermined seeps

Cities/Towns

Orito

Capella

Costayaco

HormigaLoro

Mary

Burdine/Maxine

Alea

Map datum: Magna SirgasCoord. origin: Bogot

EAST

ERNCO

RDILLERA

ECUADOR

PER

ORGA C G OC S R A AS O CO O B A


16/182



Crude Oil Quality

- Normal and light oils with API gravities ranging from 10 to 40 and sulfur contentbetween 0 and 3% are present in the basin. There is no straight relationship between

sulfur and API gravity, but oils above 30 API have sulfur values below 1%, and oilsbelow 30 show higher dispersion in sulfur content with values up to 3%. This suggeststhat in the basin there are oils with different thermal maturities,the more maturehave higher API gravity and lower sulfur content; but there are also crudes that havingsimilar API gravities have different sulfur contents, which might indicatebiodegradation, increasing sulfur content, and/or different source rocks, consideringthat oils sourced from shales usually have lower sulfur content than oils fromcarbonates (Figure A).

- The sulfur content of most crude oils is lower than 1%, and its Ni/V ratio below 0.5,suggesting that they are produced from rocks deposited in a marine suboxicenvironment with low terrigenous organic matter input (Figure C).

- There is no direct relationship between depth and crude oil quality, indicating thatsimilar quality oils can be found at different stratigraphic levels, probably related tovertical migration in faulted reservoirs. But additionally there is the fact thatdifferent API gravity oils can be found at similar depths, reflecting different

preservation (biodegradation) and/or thermal maturities (Figure B).

8

LEGEND

A

B

C

CABALLOS Fm.

PEPINO Fm.

UNKNOWN

VILLETA Fm.

0 10 20 30 40 50API Gravity

0

1

2

3

%Sulfur

Maturity

0 5 10 15 20 25 30 35 40 45 50 55 60API Gravity

20000

18000

16000

14000

12000

10000

8000

6000

4000

2000

0

Depth(Feet)

Biodegraded Oil

Heavy Oil Normal Oil Light Oil Condensates

0 1 2

Ni / V

0

1

2

3

%Sulfur

Anoxic Marine

Lacustrine or Continental



17/182

Depositional EnvironmentsORGANIC GEOCHEMISTRY ATLAS OF COLOMBIA

9 CAGUN-PUTUMAYO BASIN

- The Phytane/nC18 vs Pristane/nC17 graph indicates that most of the oils have originfrom terrestrial organic matter (Type III kerogen) deposited in an oxidizing

environment and have suffered low biodegradation. There are also some samples inthe mixed kerogen range suggesting a source with terrestrial and marine organicmatter (Type II and III kerogens) deposited in more reducing conditions (Figure A).

- The Pristane/Phytane vs Oleanane/C30 Hopane (Oleanane Index) graph shows thatmost of the oils have low oleanane index values (2) indicative of siliciclastic rocks deposited in marine deltaicenvironments (Figure C).

LEGEND

A B

C

CABALLOS Fm.

MACARENA Fm.

PEPINO Fm.

RUMIYACO Fm.

UNKNOWN

VILLETA Fm.

0.1 1 10 100Phytane / nC18

0.1

1

10

100

Pristane/nC17

Biode

gradatio

n

Matur

ity

Oxid

ixing

Reducing

Terre

strial T

ype III K

erogen

Type

II Kero

gen

Algal,

Redu

cing E

nviro

nment

Mixe

d Kero

gen I

I -III

0 1 2 3 4 5Pristane / Phytane

0

0.2

0.4

0.6

0.8

1

Oleanane/C30Hopane

Marine Deltaic

(CENOZOIC)

Shelf MarineMarine Deltaic

(CRETACEOUS)

0 1 2 3 4 5

Pristane / Phytane

0

0.5

1

1.5

2

2.5

3

C35/C34Hopane

Marine Carbonatic

Shelf Marine Marine Deltaic



18/182



Depositional Environments

- The liquid chromatography data from oils in the basin are plotted in the ternary diagram above, andtheir distribution indicate that oils are well preserved having low biodegradation (low %NSO compounds).

- In summary, the crude oils in the basin correspond predominantly with generating facies deposited in siliciclastic environments ranging frommarine to deltaic with an important terrestrial organic matter input. These rocks were deposited during the Cretaceous considering their lowoleanane index values corresponding to the Villeta and Caballos formations.

- These crude oils are of good quality with API gravities above 25 and sulfur content below 1% for most of them, and are well preserved (low

biodegradation).

- Hydrocarbons have been found in reservoirs corresponding to the Caballos, Villeta and Macarena formations of Cretaceous age and the CenozoicPepino and Rumiyaco formations.

(saturates, aromatics and NSO compunds)

10

LEGEND

CABALLOS Fm.

PEPINO Fm.

UNKNOWN

VILLETA Fm.

0 50 100

100

50

0100

50

0

%NSO%AROMATIC

%SATURATE



19/182

Chromatography

Crude oil of the Orito-16 well shows predominance of lowmolecular weight paraffins and Pristane/Phytane ratio close to1.

This crude shows predominance of tricyclics over hopanesindicating high thermal maturity. The diasteranes abundancesuggests that the oil was generated from clay-rich rocks but alsoincreased thermal maturity.

C18

C17

C16

C15

C14

C13

C12

C11

C19

C21

C20

C22

Pristane

Phytane

C10

C9

C23

C24

C25

C26

Well Orito - 16

Chromatogram

Fragmentogram m/z 191




Tricyclics

Hopanes

Diasteranes



20/182



Chromatography

Crude oil of the Unicornio-1 well shows a bimodal chromatogramwith high molecular weight paraffins abundance and very highPristane/Phytane ratio (>5.0), indicating generation from

organic facies deposited in deltaic environments.

The predominance of hopanes over tricyclics indicates lowthermal maturity of the oil. The low diasteranes abundancesuggests that the oil was generated from clay-poor rocks.

Well Unicornio - 1

Pr/Ph = 5.2

Chromatogram

Pr

Ph

Diasteranes

HopanesTricyclics



12



21/182

Source Rock CharacterizationORGANIC GEOCHEMISTRY ATLAS OF COLOMBIA

CAGUN-PUTUMAYO BASIN13

- The data obtained from pyrolysis Rock-Eval of rock samples

the depletioneffect caused by the high thermal maturity of these rocks. The data also indicate thatthe Cenozoic rocks (Mirador, Rumiyaco and Toroyaco formations) all have poorgeneration potential (Figure A).

- The Oxygen Index vs Hydrogen Index diagram (Van Krevelen diagram) shows thatrock samples from the Cretaceous Caballos, Villeta and Macarena formations havetype II oil-prone kerogen. There are also samples from these formations with type IIIgas-prone characteristics. In the case of the Cenozoic units (Mirador, Arrayn,Rumiyaco and Toroyaco formations) their samples are indicative of type III gas-prone

kerogen to type IV kerogen. The Paleozoic samples have very low HI values andcorrespond mainly with type IV kerogen (Figure B).

-

for Hydrogen Index(HI) and S2 peak, indicate that samples from the Cretaceous Caballos, Villeta and

Macarena formations have good generation potential (HI > 200mg HC/g TOC and S2 > 5mg HC/g rock). Taking into account that these units are deeply buried in the basin,the poor generation values obtained from some samples could reflect

The Tmax maturity parameter vs Hydrogen Index graph shows that many samplesfrom the Cretaceous to Cenozoic units mentioned, have reached early maturity to oilgeneration peak conditions in the basin (Figure C).

LEGEND

A B

C

ARRAYAN Fm.

CABALLOS Fm.

MACARENA Fm.

MIRADOR Fm.

PALEOZOIC

RUMIYACO Fm.

TOROYACO Fm.

UNKNOWN

VILLETA Fm.

0 10 20 30 40 50 60 70 80 90S2 (mgHC / gROCK)

0

100

200

300

400

500

600

700

800

900

HydrogenIndex(mgHC/gT

OC)

Poor Generation Potentialand/or High thermal maturity

Excellent Generation PotentialLow thermal maturity

0 50 100 150 200 250 300

Oxygen Index (mg CO2 / gTOC)

0

100

200

300

400

500

600

700

800

900

1000

HydrogenIndex(mgHC/gT

OC)

I

I I

I I I

IV

370 390 410 430 450 470 490 510 530 550

Tmax (oC)

0

200

400

600

800

1000

H

ydrogenIndex(mgHC/gTOC)

I

II

III

0.5%

Ro


1.35% Ro


22/182


23/182



24/182


Caballos Fm. Villeta Fm.

Hydrogen Index

650000 700000 750000 800000 850000 900000 950000 1000000 1050000 1100000 1150000

300000

350000

400000

450000

500000

550000

600000

650000

700000

750000

800000

850000

12

1622

33

35

50mg HC/g TOC

150mg HC/g TOC

250mg HC/g TOC

350mg HC/g TOC

650000 700000 750000 800000 850000 900000 950000 1000000 1050000 1100000 1150000

300000

350000

400000

450000

500000

550000

600000

650000

700000

750000

800000

850000

12

1622

23

33

0mg HC/g TOC

40mg HC/g TOC

80mg HC/g TOC

120mg HC/g TOC

160mg HC/g TOC

200mg HC/g TOC

Source Rock Quality and Maturity Maps

16

1. ACAE-22. AZUL GRANDE-23. BAGRE WEST-14. BURDINE-15. CAFELINA-16. CALDERO-1

7. CARIBE-48. CONDOR-19. CONEJO-110. DOLORES-111. EVELYN-112. GARZA-1

LEGEND

13.GAVILAN WEST-214. HORMIGA-1X15. LAS CHICAS-116. LUCILLE-117. MANDUR-118. MANDUR-3

19. MIRAFLOR-120. NANCY-121. ORITO SUR-122. ORITO-2023. PINUNA-124. PUERTO ASIS-1

25. QUILILI-126. QUILLACINGA-127. RO MOCOA-128. RO PESCADO-129. RO SEVILLA-130. SETUKO-1

31. SUCUMBIO-232. TEMBLN-1X33. TOROYACO-134. TUCN-135. URIBE-136. VENADO-1




25/182

Caballos Fm. Villeta Fm.

Organic Matter Content (TOC)

650000 700000 750000 800000 850000 900000 950000 1000000 1050000 1100000 1150000

300000

350000

400000

450000

500000

550000

600000

650000

700000

750000

800000

850000

6912

1622

31

33

35

0.6% wt

0.9% wt

1.2% wt

1.5% wt

1.8% wt

650000 700000 750000 800000 850000 900000 950000 1000000 1050000 1100000 1150000

300000

350000

400000

450000

500000

550000

600000

650000

700000

750000

800000

850000

612

1622

23

33

0.2% wt

0.8% wt

1.4% wt

2% wt

2.6% wt


1. ACAE-22. AZUL GRANDE-23. BAGRE WEST-14. BURDINE-15. CAFELINA-16. CALDERO-1

7. CARIBE-48. CONDOR-19. CONEJO-110. DOLORES-111. EVELYN-112. GARZA-1

LEGEND

13.GAVILAN WEST-214. HORMIGA-1X15. LAS CHICAS-116. LUCILLE-117. MANDUR-118. MANDUR-3

19. MIRAFLOR-120. NANCY-121. ORITO SUR-122. ORITO-2023. PINUNA-124. PUERTO ASIS-1

25. QUILILI-126. QUILLACINGA-127. RO MOCOA-128. RO PESCADO-129. RO SEVILLA-130. SETUKO-1

31. SUCUMBIO-232. TEMBLN-1X33. TOROYACO-134. TUCN-135. URIBE-136. VENADO-1





26/182


Petroleum Systems (Crude-Rock Correlations)

18

- The Pristane/Phytane vs Oleanane/C30 Hopane (Oleanane Index) graph shows thatoils from the Caballos, Villeta, Pepino and Rumiyaco reservoirs have low oleananeindex values (


27/182

Petroleum Systems (Crude-Rock Correlations)

- The Homohopanes Index (C35/C34 Hopane ratio) vs diasteranes/steranes graph shows good correlation between the crude oils from the

Caballos, Villeta and Pepino reservoirs with rock extracts from the Caballos and Villeta formations, indicating also that these crudes wereformed from rocks deposited in suboxic environments with variable clay content (Figure A).

- The Ts/(Ts+Tm) vs diasteranes/steranes graph shows good correlation between crude oils from the Caballos, Villeta and Pepino formationswith rock extracts from the Caballos and Villeta formations. In this graph there is better correlation of Caballos formation crudes withVilleta formation extracts than with Caballos formation extracts, and of Villeta formation oils with Caballos and Villeta extracts.Additionally this graph suggests that oils were formed from clay-poor rocks.

Crude - Rock correlations from samples at the basin suggest the following:

- Good correlation between crudes from the Caballos, Villeta and Pepino reservoirs and extracts from the Villeta and Caballos formations(low diasteranes/steranes, low Ts/Tm, C35/C34 hopane ratio < 1, low oleanane index, Pristane/Phytane < 2, and predominance of C27/C29steranes).

- This indicates the presence of several active petroleum systems at the basin named as follows: Caballos (!), Caballos (!), Villeta(!), Villeta - Pepino (!) and Caballos - Pepino (!).

Villeta -


LEGEND

A B

0 2 4 6 8 10 12Diasteranes / Steranes

0

0.4

0.8

1.2

1.6

2

C35/C34HopaneRatio

DECREASING CLAY CONTENT (CARBONATES) ORHIGH REDUCING CONDITIONS (ANOXIC)

INCREASING CLAY CONTENT (SHALES) ORLOW REDUCING CONDITIONS (OXIC)

CRUDE- CABALLOS Fm.

CRUDE- PEPINO Fm.

CRUDE- RUMIYACO Fm.

CRUDE- VILLETA Fm.

ROCK- CABALLOS Fm.

ROCK- RUMIYACO Fm.

ROCK- VILLETA Fm.

0 2 4 6 8 10 12Diasteranes / Steranes

0

0.4

0.8

1.2

1.6

2

Ts/(Ts+Tm)

INCREASING CLAY CONTENT

DECRESING CLAY CONTENT (CARBONATES)



28/182

CATATUMBO BASIN

GeneralitiesWells and SeepsCrude Oil QualityDepositional Environments

ChromatographySource Rock CharacterizationSource Rock Quality and Maturity MapsGas Characterization

G liti



29/182

From Barrero et al, 2007

Fluvial

Uri

ban

teGr.

STRATIGRAPHICUNITS

Fluvial

Stream

Aguardiente

Capacho Fm.

La Luna Fm.

Coln Fm.

Mito-Juan Fm.Catatumbo Fm.Barco Fm.

Los Cuervos Fm.

Mirador Fm.

Carbonera Fm.

Len Fm.

Guayabo Fm.

NEOGENE

PALEOGENE

CRETACEOUS

JURASSIC

Mercedes

TibRo Negro

Girn Gp.

La Quinta Fm.

LITHOLOGY ENVIRONMENT

Generalities

The source rock geochemical informationinterpreted for the Catatumbo Basin

includes %TOC and Rock-Eval Pyrolysisdata from 1195 samples taken in 33 wells;additionally 343 organic petrographysamples from 21 wells were interpreted.

Crude oil information from 146 bulkanalysis samples, 235 liquid chromatographysamples, 275 gas chromatography samples,242 biomarker samples and 170 isotopessamples were also interpreted.

CATATUMBO BASIN21

Pacific Ocean

Caribbean Sea

VENEZUELA

BRAZIL

PERU

ECUADOR

PANAMA

COLOMBIA

BarranquillaSanta Marta

Valledupar

Cucuta

Bucaramanga

VENEZUELAB.S.M.F 03

CATATUMBO BASINLOCATION AND BOUNDARIES

7

8

9

10

11

72 71737475

72 71737475

7

8

9

10

11

BOUNDARIESNorth: Geographic Border with Venezuela

South: Eastern Cordillera Cretaceous rocks

West: Santader Massif igneous and metamorphics

East: Geographic Border with Venezuela

B.S.M.F. Bucaramanga-Santa Marta Fault System


Catatumboflexure zone

Easternflexure zone

SCHEMATIC CROSS SECTIONCATATUMBO BASIN

W E

Basement Lower Cretaceous

Cenozoic

Upper Cretaceous


10Km

1000m

0

scale approx..

Modified from Yurewicz, et al., 1998




30/182

CATATUMBO BASIN

Wells and Seeps

The number of wells and/or surface locationswith geochemical information in the Catatumbo

Basin is 56.

Seeps are located at the northwestern andeastern parts of the basin. Oil fields are mostlylocated to the east of the basin.

22

CUCUTA

1120000 1140000 1160000 1180000

1340000

1360000

1380000

1400000

1420000

1440000

1460000

1480000

1500000

0 10 20Kms

Oil and gas fields


Oil seeps

Gas seeps

Undetermined seeps

Cities/Towns

Puerto Barco

Ro de Oro

Tib - Socuavo

Yuca

Sardinata

Petrolea

Carbonera

Ro Zulia

VENEZUELA

EASTERNCORDILLERA


TIB

PUERTOSANTANDER

Crude Oil Quality



31/182

Crude Oil Quality

CATATUMBO BASIN23

- Normal and light oils with API gravities ranging from 25 to 45 and sulfur contentbetween 0 and 1.2% are present in the basin. There is a straight relationship between

sulfur and API gravity, showing that high API gravity mature oils have low sulfurcontent regarding low API gravity less mature oils. (Figure A).

- The sulfur content of most crude oils is lower than 1%, and its Ni/V ratio below 1,suggesting that they are produced from rocks deposited in a marine suboxic to anoxicenvironment with marine organic matter input (Figure C).

- There is no direct relationship between depth and crude oil quality, indicating thatsimilar quality oils can be found at different stratigraphic levels, probably related tovertical migration in faulted reservoirs. But additionally there is the fact thatdifferent API gravity oils can be found at similar depths, reflecting differentpreservation (biodegradation) and/or thermal maturities (Figure B).

-The oils of the Catatumbo Basin are of excellent quality, with high API gravity andlow sulfur content and its high thermal evolution explains the high API gravity.

LEGEND

AB

C

AGUAS BLANCAS Fm.

BARCO Fm.

BARCO - LOS CUERVOS Fm.

COGOLLO Fm.

LA LUNA Fm.

MITOJUAN Fm.

UNKNOWN

URIBANTE Gr.

0 5 10 15 20 25 30 35 40 45 50 55 60API Gravity

20000

18000

16000

14000

12000

10000

8000

6000

4000

2000

0

Depth(Feet)

Biodegraded Oil

Heavy Oil Normal Oil Light Oil Condensates

20 30 40 50 60API Gravity

0

0.4

0.8

1.2

1.6

2

%Sulfur

Maturity

0 1 2

Ni / V

0

1

2

%Sulfur

Anoxic Marine

Lacustrine or Continental




32/182

CATATUMBO BASIN


24

- The Phytane/nC18 vs Pristane/nC17 graph indicates that most of the oils have originfrom mixed terrestrial-marine organic matter (Type II-III kerogens), have sufferedlow biodegradation and are thermally mature. There are some samples in theterrestrial kerogen range suggesting a source with terrestrial organic matter (Type IIIkerogen) deposited in more oxidizing conditions (Figure A).

- The API Gravity vs C29aBB/C29aBB+aaa graph, shows that oils with higher APIgravity has higher C29 isomerization and close to equilibrium (stability boundary) asa result of their high thermal maturity (Figure B).

- The Pristane/Phytane vs C35/C34 Hopane (Homohopane index) graph shows thatmost oil samples have Pr/Ph values below 2 and C35/C34 Hopane above 1, indicatingthat these oils were generated from rocks with variable carbonatic input deposited in

a shelf marine environment. Additionally there is one sample with low homohopaneindex but higher Pr/Ph values (>2) indicative of siliciclastic rocks deposited in marinedeltaic environments (Figure C).

LEGEND

A

B

AGUAS BLANCAS Fm.

BARCO Fm.

ESCANDALOSA Fm.

MITOJUAN Fm.

UNKNOWN

URIBANTE Gr.

YURUMA SUPERIOR Fm.

LA LUNA Fm.

COGOLLO Fm.

0.1 1 10 100Phytane / nC18

0.1

1

10

100

Pristane/nC17

Biode

gradatio

n

Matur

ity

Oxid

ixing

Reducing

Terre

strial T

ype III K

erogen

Type

II Kero

gen

Algal,

Redu

cing E

nviro

nment

Mixe

d Kero

gen I

I -III

0 10 20 30 40 50 60API Gravity

0

0.1

0.2

0.3

0.4

0.5

0.6

0.7

0.8

C29abb

/C29abb+aaa

Maturity

Stability boundary

Marine Carbonatic

Shelf Marine Marine Deltaic

0 1 2 3 4 5

Pristane / Phytane

0

0.5

1

1.5

2

2.5

3

C35/C34Hopane




33/182


CATATUMBO BASIN25

-

- In summary, the crude oils in the basin correspond predominantly with generating facies deposited in marine carbonatic and siliciclasticenvironments, with low terrestrial organic matter input. These rocks were deposited during the Cretaceous considering their low oleanane indexvalues and t

correspond to the La Luna and Capacho formations and the Uribante Group.

- These crude oils are of good quality with API gravities above 25 and sulfur content below 1% for most of them, and are well preserved (lowbiodegradation).

The Pristane/Phytane vs Oleanane/C30 Hopane (Oleanane Index) graph shows that most of the oils have low oleanane index values (


34/182

CATATUMBO BASIN

Chromatography

The crude oil of the Tib-366 well is characterizedby showing in gas chromatography, predominanceof low molecular weight paraffins (high thermalmaturity) and Pristane/Phytane ratio < 1.0.

.

The high degree of thermal evolution of the oilhas reduced the hopanes and steranes abundanceand increased the tricyclics in the oil

5 10 15 20 25 30

counts

10000

20000

30000

40000

50000

60000

70000

FID1 A, (GEOQ1107\2897755.D)

N-C11

N-C12

N-C13

N-C14

N-C15

N-C16

N-C17

Pri

stane N

-C18

Phytane

N-C19

N-C20

N-C21

N

-C22

N-C23

N-C

24

N-C2

5

N-C26

N-C27

N-C28

N-C29

N-C30

Well Tib - 366

Chromatogrammin

20.00 25.00 30.00 35.00 40.00 45.00 50.00 55.00 60.00 65.00 70.00 75.00

2000

4000

6000

8000

10000

12000

14000

16000

Time-->

Ion 191.00 (190.70 to 191.70): C-TIB366.D

20.00 25.00 30.00 35.00 40.00 45.00 50.00 55.00 60.00 65.00 70.00 75.00

500

1000

1500

2000

2500

3000

3500

Abundance

Ion 217.00 (216.70 to 217.70): C-TIB366.D

Time-->



26

Tricyclics

Hopanes

Diasteranes

Source Rock Characterization



35/182


27 CATATUMBO BASIN

- The data obtained from pyrolysis of rock samples

thedepletion effect caused by the high thermal maturity of these rocks. The data alsoindicate that most of the Cenozoic rocks (Mirador, Los Cuervos, Len and Guayaboformations), have poor generation potential with the exception of the Barco andCarbonera formations which have samples with good generation potential (Figure A).

- The Oxygen Index vs Hydrogen Index diagram (Van Krevelen diagram) shows thatrock samples from the Cretaceous Uribante Group and La Luna, Capacho andCatatumbo formations, along with the Cenozoic Barco and Carbonera formationshave type II oil-prone kerogen. Some samples of these units also have type III kerogenvalues. The Cretaceous Mito-Juan Formation and the Cenozoic units (Mirador and LosCuervos formations) have samples predominantly of type III gas-prone kerogen totype IV kerogen. (Figure B).

-

for Hydrogen Index (HI) and S2peak, indicate that most samples have poor generation potential (HI < 200mg HC/gTOC and S2 < 5 mg HC/g rock), and there are few samples with good generationpotential (HI > 200mg HC/g TOC and S2 > 5 mg HC/g rock).In the case of theCretaceous rocks should be considered that these units are deeply buried in the

basin, and the poor generation values obtained from some samples could reflect

The Tmax maturity parameter vs Hydrogen Index graph shows that many samplesfrom the Cretaceous to Cenozoic units mentioned, have reached early maturity toovermature conditions in the basin, being the Cretaceous units more mature than theCenozoic units, explaining the high thermal maturity indicated by the oils found inthe basin (Figure C).

LEGEND

A B

C

370 390 410 430 450 470 490 510 530 550

Tmax (oC)

0

200

400

600

HydrogenIndex(mgHC/gTOC

)

III

III

1.35% Ro

0.5

%

Ro


BARCO Fm.

CARBONERA Fm.

CATATUMBO Fm.

COGOLLO Fm.

COLN Fm.

COLON/LA LUNA Fm.

CAPACHO Fm.GUAYABO Fm.

LA LUNA Fm.

LA LUNA/COGOLLO Fm.

LEN Fm.

LOS CUERVOS Fm.

MIRADOR Fm.

MITO JUAN Fm.

OSTREA Fm.

UNKNOWN

URAMITA Fm.

URIBANTE Gr.

0 10 20 30 40

S2 (mgHC / gROCK)

0

100

200

300

400

500

HydrogenIndex(mgHC/g

TOC)


Excellent Generation Potential

Low thermal maturity

0 50 100 150 200 250


0

100

200

300

400

500

HydrogenIndex(mgHC/g

TOC)

I I I

I I I

IV




36/182

CATATUMBO BASIN 28

- Organic content (%TOC) and S2 peak values indicate source rock oil generation potential, this graph shows that there are samples fromCretaceous units (Uribante Group, La Luna, Capacho and Catatumbo formations) and Cenozoic units (Barco, Los Cuervos and Carboneraformations), with good to excellent oil generation potential (S2 up to 35 mg HC/g rock and % TOC up to 9). In the case of the UpperCretaceous Mito-Juan Formation and the Cenozoic Guayabo and Len formations their samples indicate poor oil generation potential

(Figure A). G

-The vitrinite reflectance (%Ro) information shows that the sedimentary sequence deposited in the basin is mostly mature to overmaturewhich is in good agreement with the API Gravity and high thermal maturity of the oils found (Figure B).

-In summary, the best source rocks at the basin, with good to excellent oil generation potential intervals are the Cretaceous rocks of theUribante Group, and La Luna, Capacho and Catatumbo formations. The Cenozoic rocks of the Barco and Carbonera formations also havegood to excellent generation potentials. Thermal maturity data (Tmax and %Ro) indicates that the Cretaceous oil-prone formations are themore mature sources for the hydrocarbons in the basin, and that the Cenozoic Barco and Carbonera formations are also in an earliermaturity stage in the basin.

(S2 2.0, C35/C34 hopanes 5 mg HC/g rock) were obtainedfrom the Cretaceous Chapungo Sequence, and from the Cenozoic Chimborazo,Guachinte, Mosquera and Esmita formations

The Tmax maturity parameter vs Hydrogen Index graph shows that many samples

from the Cretaceous to Cenozoic units mentioned are mature to overmature in thebasin (Figure C). There is no clear correlation between stratigraphic position andthermal maturity, because younger and older rocks have similar maturities, whichsuggests that there is some process in the basin affecting in the same way the wholestratigraphic sequence, possibly related to the extensive presence of intrusive rocksin the basin.

LEGEND

A B

C

0 10 20 30 40 50 60 70 80 90 100

S2 (mg HC / gROCK)

0

100

200

300

400

500



Excellent Generation Potential

Low thermal maturity

AGUA CLARA Fm.

CHIMBORAZO Fm.

DIABASICO Gr.MOSQUERA Fm.

PEA MORADA Fm.

RIO GUABAS SECTION

CHAPUNGO SEQUENCE

UNKNOWN

CINTA DE PIEDRA Fm.

ESMITA Fm.

FERREIRA Fm.

GUACHINTE Fm.

0 50 100 150 200 250 300


0

100

200

300

400

500


I I I

I I I

IV

370 390 410 430 450 470 490 510 530 550

Tmax (oC)

0

200

400

600


III

III

1.35% Ro

0.5

%

Ro




45/182

37 CAUCA - PATA BASIN

- Organic content (%TOC) and S2 peak values indicate source rock oil generation potential, this graph shows that there are samples fromCretaceous (Chapungo sequence) and Cenozoic units (Mosquera, Ferreira, and Esmita formations)

(Figure A).

-The vitrinite reflectance (%Ro) information shows that most of the samples are immature or close to early maturity in the basin.However some samples are in the oil generation window and even overmature in accordance with Tmax data. In this graph it isimportant to notice that due to the fact that the samples were taken from outcrops, the depth is a relative depth corresponding to thestratigraphic position of the samples in the field column and not burial depths (Figure B).

-In summary, the best source rocks at the basin, with good to excellent oil generation potential intervals are the Cretaceous rocks of the

Chapungo Sequence and the Cenozoic rocks of the Mosquera, Ferreira and Esmita formations. Maturity data from outcrop samplesindicate that the oil-prone formations are mature for hydrocarbons generation, and that good quality oils could be expected from thehigh thermal maturity reached by some potential source rocks in the basin.

with good to excellent oil generationpotential (S2 up to 50 mg HC/g rock and % TOC up to 9). Additionally this graph shows that samples from the Cretaceous Ro GuabasFormation and Cenozoic Mosquera and Cinta de Piedra formations, although have good to excellent TOC values (up to 10 wt%), do nothave good S2 values (< 5 mg HC/g rock), indicating that the kerogen in these formations is not labile and appropriate for liquidhydrocarbons generation

LEGEND

A

BAGUA CLARA Fm.

CHIMBORAZO Fm.

DIABASICO Gr.

MOSQUERA Fm.

PEA MORADA Fm.

RIO GUABAS SECTIONCHAPUNGO SEQUENCE

UNKNOWN

CINTA DE PIEDRA Fm.

ESMITA Fm.

FERREIRA Fm.

GUACHINTE Fm.

0 2 4 6 8 10

%TOC

0

10

20

30

40

S2(mgHC/gROCK)

Excellent

Very Good

Good

Fair

Poor

0.1 1 10

%Ro

12000

11000

10000

9000

8000

7000

6000

5000

4000

3000

2000

1000

0

Depth(Feet)

Immature Overmature(Gas Window)

OilWindow


Surface Geochemistry


46/182

CAUCA- PATA BASIN

Compositional data from surface geochemistry samplesindicate that most of the hydrocarbons in the basin arethermogenic, formed mainly during oil generationwindow with minor presence of high maturity

hydrocarbons (gas generation window).

(Figure A).

Isotopic data from these type of samples indicatethermogenic origin of the gases with mixing betweendifferent thermal maturity hydrocarbons, generationfrom type II and III kerogens, and to a minor extentmicrobial oxidation (Figure B).

There are veryfew samples of microbial gas to consider biogenic gas animportant process in the basin.

38

LEGENDA

B

0 1 2 3 4 50.5 1.5 2.5 3.5 4.5

C2/(C3+C4)

1

10

100

1000

C1/(C2+C3)

Microbial gas

Dry gas

Mixed deep

gas

Condensate Mixed

Oil

UNKNOWN

-100 -90 -80 -70 -60 -50 -40 -30 -20-95 -85 -75 -65 -55 -45 -35 -25

d13C Methane (o/oo)

1

10

100

1000

10000

100000

C1/(C2+C3)

BacterialPredominantly methyltype fermentation

PredominantlyCO2 reduction

Microbialoxidation

Mixed

Type II Kerogen

Type III Kerogen

Thermogenic



47/182

CESAR RANCHERIA BASIN


Source Rock CharacterizationSource Rock Quality and Maturity Maps



CESAR RANCHERA BASIN

Generalities


48/182


SCHEMATIC CROSS SECTIONCESAR - RANCHERIA BASIN

W E

Basement Cretaceous CenozoicUpper Cretaceous


0

1

2

3

4

secTime

CESAR RANCHERA BASINLOCATION AND BOUNDARIES

Pacific Ocean

Caribbean Sea

VENEZUELA

BRASIL

PERU

ECUADOR

PANAMA

COLOMBIA

BOUNDARIES

SW: Bucaramanga-Santa Marta Fault (B.S.M.F)

E-SE: Pre-Cretaceous rocks of the

de Perij (22); Colombian-Venezuelanboundary.

Serrana

NE: Oca Fault (O.F.)

NW: Pre-Cretaceous rocks of the Sierra Nevadade Santa Marta (23)

Caribbean Sea

RiohachaSanta Marta

BarranquillaValledupar

22

05

VENEZUELA

B.S.M.F

72 71737475

9

10

11

12

72 71737475

9

10

11

12

23

22

PALEOGENE

NEOGENE

RESERVOIR

SOURCE

LITHOLOGYTRAP

RANCHERIACESAR C R C R

? ?

? ?

? ?

? ?

STRAT. UNITS

CESAR RANCHERIA

STRAT. UNITS

GENERATION

MIGRATION

La Jagua

Barco Fm.

Delicias Fm.

Molino Fm.

Laja/La Luna

Aguas Blancas

Lagunitas Fm.

Ro negro Fm.

La Quinta Fm.

Cachiri Gp.

Volcanoclastics

Cerrejn Fm.

Manantial Fm.

Hato Nuevo

Manaure Fm.

Laja/La Luna

Aguas Blancas

Lagunitas Fm.

Ro negro Fm.

La Quinta Fm.

Cachiri Gp.

Palmito Sh.Tabaco Ss.

ConjuntoCalcreo

ConjuntoConglomertico

CRETACEOUS

JURA.

HIATUS

HIATUS

Limestones Sandstones Shales Conglomerates Coals

The source rock geochemical informationinterpreted for the Cesar - Ranchera Basinincludes %TOC and Rock-Eval Pyrolysis data from417 samples taken in 4 wells and 81 samples from

outcrops; additionally 91 organic petrographysamples from 4 wells and 62 samples fromoutcrops, and 417 surface geochemistry sampleswere also interpreted.

Due to the lack of crude oil geochemical data,crude oil interpretation can not be made for thebasin.

40




Wells and Seeps



49/182

The number of wells and/or surface locations withgeochemical information in the Cesar - Ranchera

Basin is 18.

CESAR-RANCHERIA BASIN41

VALLEDUPAR

1020000 1040000 1060000 1080000 1100000 1120000 1140000 1160000 1180000

1520000

1540000

1560000

1580000

1600000

1620000

1640000

1660000

1680000

1700000

1720000CERREJON-1

CESAR A-1X

Cesar F-1X

CESAR H-1X

CH31

COMPAE-1

EL MOLINO-1

EL PASO-1

EL PASO-2

EL PASO-3EL PASO-4

LOS VENADOS-1

M75MM194

MOLINO 1-X

MS63

PAPAYAL-1

RIO MARACAS-1

0 25 50Kms



Oil seeps

Cities/Towns

FONSECA

LA JAGUADE IBIRICO


Source Rock CharacterizationLEGEND

600I I I


50/182

CESAR RANCHERIA BASIN 42

A B

C

- The data obtained from pyrolysis of rock samples

(Figure A).

- The Oxygen Index vs Hydrogen Index diagram (Van Krevelen diagram) shows thatrock samples from the Cretaceous Lagunitas, Aguas Blancas, La Luna and Molinoformations have type II oil-prone kerogen. The Cenozoic Los Cuervos Formation alsohas type II kerogen, but there are samples from this formation and the CretaceousMolino Formation with type III gas-prone kerogen in the basin. (Figure B).

-

for Hydrogen Index (HI) and S2peak, indicate that samples from the Cretaceous Aguas Blancas, La Luna and Molino

formations and the Cenozoic Los Cuervos Formations have good generation potential(HI > 200mg HC/g TOC and S2 > 5 mg HC/g rock).

The Tmax maturity parameter vs Hydrogen Index graph shows that many samplesfrom the Cretaceous to Cenozoic units mentioned, have reached early maturityovermature conditions in the basin. Maturity increases with burial depth being theEarly Cretaceous rocks (Ro Negro, Lagunitas and Aguas Blancas formations) more

mature, with samples of the Lagunitas, La Luna and Molino formations at the oilgeneration peak (Figure C).

AGUAS BLANCAS Fm.

LA LUNA Fm.

LAGUNITAS Fm.

MOLINO Fm.

RIO NEGRO Fm.

UNKNOWN

LA QUINTA Fm.

LOS CUERVOS Fm.

0 10 20 30 40

S2 (mgHC / gROCK)

0

100

200

300

400

500


Poor Generation Potential

and/or High thermal maturity


0 50 100 150 200 250 300


0

100

200

300

400

500

HydrogenIndex(mgHC/

gTOC)

I I

I I I

IV

370 390 410 430 450 470 490 510 530 550

Tmax (oC)

0

200

400

600

HydrogenIndex(mgHC/gTO

C)

III

III

1.35% Ro

0.5

%

Ro




40 0

Immature Overmature


51/182

LEGEND LEGEND

43 CESAR-RANCHERIA BASIN

AB

- Organic content (%TOC) and S2 peak values indicate source rock oil generation potential, this graph shows that there are samples fromCretaceous (Lagunitas, Aguas Blancas, La Luna, and Molino formations ) and Cenozoic units (Los Cuervos Formation)

(Figure A).

-The vitrinite reflectance (%Ro) information shows that many samples in the basin are mature or overmature at the Cesar A-1X and

Compae-1 well locations to the south of the basin, and less mature at the El Molino-1X and El Paso-3 wells to the north. (Figure B).

-In summary, the best source rocks at the basin, with good to excellent oil generation potential intervals are the Cretaceous rocks of theLagunitas,Aguas Blancas, La Luna and Molino formations and the Cenozoic rocks of the Los Cuervos formation. Maturity data indicatethat the oil-prone formations are mature for hydrocarbons generation, and that good quality oils could be expected from the highthermal maturity reached by potential source rocks in the basin.

with good toexcellent oil generation potential (S2 up to 50 mg HC/g rock and % TOC up to 9). Additionally this graph shows that samples from theCretaceous Lagunitas Formation and Cenozoic Los Cuervos Formation, although have good to excellent TOC values (up to 10 wt%), donot have good S2 values (< 5 mg HC/g rock), indicating that the kerogen in these formations is not labile and appropriate for liquidhydrocarbons generation

AGUAS BLANCAS Fm.

LA LUNA Fm.

LAGUNITAS Fm.

MOLINO Fm.

RIO NEGRO Fm.

UNKNOWN

LA QUINTA Fm.LOS CUERVOS Fm.

0 2 4 6 8 10

%TOC

0

10

20

30

S2(mgHC/gROCK)

Excellent

Very Good

Good

Fair

Poor

CESAR A-1X

COMPAE-1

EL MOLINO-1X

EL PASO-3

0.1 1 10

%Ro

12000

11000

10000

9000

8000

7000

6000

5000

4000

3000

2000

1000

Depth(Feet)

Immature Overmature(Gas Window)

OilWindow




52/182


Vitrinite Reflectance (%Ro) Hydrogen Index

La Luna Formation

1020000 1040000 1060000 1080000 1100000 1120000 1140000 1160000 1180000

1520000

1540000

1560000

1580000

1600000

1620000

1640000

1660000

1680000

1700000

1720000

COMPAE-1

EL MOLINO-1X

0.46% Ro to 0.61% Ro0.61% Ro to 0.75% Ro

1020000 1040000 1060000 1080000 1100000 1120000 1140000 1160000 1180000

1520000

1540000

1560000

1580000

1600000

1620000

1640000

1660000

1680000

1700000

1720000

COMPAE-1

253mg HC/g TOC

44





53/182

Organic Matter Content (TOC)

La Luna Formation

1020000 1040000 1060000 1080000 1100000 1120000 1140000 1160000 1180000

1520000

1540000

1560000

1580000

1600000

1620000

1640000

1660000

1680000

1700000

1720000 CH31

M75 MM194

MS63

COMPAE-1

0% wt

1% wt

2% wt

3% wt

4% wt

45 CESAR-RANCHERIA BASIN




1000


54/182


LEGEND

Compositional data from surface geochemistry samplesindicate that hydrocarbons are thermogenic, formedmainly during late oil generation window (condensates)with minor presence of high maturity hydrocarbons (gas

generation window) with some mixing between differentthermal maturity hydrocarbons.

Isotopic data indicates thermogenic generation fromprobably type II and type III kerogens

There is no evidence of microbial gas in the basin.

46

A

B

UNKNOWN

0 1 2 3 4 50.5 1.5 2.5 3.5 4.5

C2/(C3+C4)

1

10

100

1000

C1/(C2+C3)

Microbial gas

Dry gasMixed deep

gas

Condensate Mixed

Oil

-100 -90 -80 -70 -60 -50 -40 -30 -20-95 -85 -75 -65 -55 -45 -35 -25

d13C Methane (o/oo)

1

10

100

1000

10000

100000

C1/(C2+C3)

BacterialPredominantly methyltype fermentation

PredominantlyCO2 reduction

Microbialoxidation

Mixed

Type II Kerogen

Type III Kerogen

Thermogenic



55/182

CHOC BASIN


Source Rock CharacterizationSurface Geochemistry


Generalities


56/182

CHOC BASIN 48

W E

SCHEMATIC CROSS SECTIONCHOCO BASIN

Oceanic Crust Paleocene Neogene


sec

0

1

2

3

Pacific Ocean

Caribbean Sea

VENEZUELA

BRAZIL

PERU

ECUADOR

PANAMA

COLOMBIA

CHOC BASINLOCATION AND BOUNDARIES

BOUNDARIESN-NW: Geographic border of Panam

South: Garrapatas fault zone (G.F.Z.)

NW: Serrana de Baud (SB)

SW: Present Pacific coastline

East:

Cretaceous rocks of the WesternCordillera (WC) and partially theMurind fault (M.F.)

Mande quartzdiorite (M.B.), the

PANAMA

06 Medellin

Ibagu

Pacific Ocean

U.F S.

..G3

4

5

75767779 7880

6

7

8

75767779 7880

3

4

5

6

7

8

SBM.B.

WC

M.F

Quibd

The source rock geochemical information interpreted forthe Choc Basin includes %TOC and Rock-Eval Pyrolysisdata from 168 samples taken in 2 locations; additionally 68

organic petrography samples from 2 locations, and 333surface geochemistry samples were interpreted.

Due to the lack of crude oil geochemical data, crude oilinterpretation was not made for the basin.


From Barrero et al., 2007From Mojica et al.,, 2010

D

2500

MUNGUID

4500

500

4300

SANJUAN

CONGL.

LAMOJARRA

ISTMINA

SIERR

A

OLIG

IR

1000

CONDOTO

2.5-5-AVERAGE3.75

3-8-AVERAGE5.5

CAA

SGORDAS

LAEQUIS

STA.CECILIA

?

?

PERIOD

GROUP

FORMATION

LITHOLOGY

DTHICKNESS(m)

TOC

SCI

PETROLEUM

SYSTEM

SANDSTONES

PLIOCENE

PLEISTOCENE

2500

MUNGUID

UPPERMIOCENE

4500

500

4300

SANJUAN

LOWERMIOCENE

CONGL.

LAMOJARRA

ISTMINA

SIERR

A

OLIG

IR

PALEOCENE-EOCENE

ATRATO

1000

CONDOTO

CONGLOMERATES

0.35%-0.70%-AVERAGE:0.57%

0.23%-13.6%-AVERAGE:3.8%

CRETACEOUS

CAA

SGORDAS

LAEQUIS

STA.CECILIA

?

?

MANDEBAT

HOLITH

LIMESTONES,MUDROCKS,CHERTS.

SILTSTONESAND LITHIC

SANDSTONES

DARKMUD STONES,MARLSAND

CHERTS.

DIABASES,BASALTSAND BASIC

TUFFS,WITH DIFFERENT

SEDIMENTARYBEDS

SANDSTONESINTERBEDDEDWITH

MUDSTONES.

LIMESTONESAND MUDSTONES

INTERBEDDEDWITH IMPURE

SANDSTONES.

SILTSTONESAND CLAYSTONESWITH

BEDSOFCONGLOM ERATESAND

SANDSTONES.

CONGLOMERATES

CLAYSTONES

LIMESTONES

SANDSTONES,CONGLOMERATIC

SANDSTONESAND SILTSTONES.

BASALCONGLOMERATE,

SANDSTONESAND MUDSTONES.

LIMESTONES,SANDSTONESANDMUDSTONES.

LIMESTONESAND MARLS

INTERBEDDEDWITH CHERTAND

MUDSTONES.SANDSTONE

INTERCALATIONSIN THETOP.

Atrato Sub-Basin San Juan Sub-Basin

Wells and Seeps



57/182

The number of wells and/or surface locations withgeochemical information in the Choc Basin is 2.

Oil seeps are mainly located at the southern andeastern parts of the basin.

CHOC BASIN49

QUIBD

600000 650000 700000 750000

950000

1000000

1050000

1100000

1150000

1200000

1250000

1300000

1350000

BUCHADO-1

0 25 50Kms



Oil seeps

Gas seeps

Undetermined seeps

Cities/Towns

PACIFICOCEAN

WESTERN

CORDILLERA

PANAM

BAHASOLANO

ITSMINA

RIOSUCIO



A B600

700


58/182

CHOC BASIN

LEGEND

50

A B

C - The data obtained from pyrolysis of rock samples

l (Figure A).

- The Oxygen Index vs Hydrogen Index diagram (Van Krevelen diagram) shows thatrock samples from the Paleogene Ir Formation have type I and II oil-prone kerogens.In the case of the Neogene Itsmina and Conglomerado de la Mojarra formations theirsamples are indicative of type III gas-prone kerogen to type IV kerogen. (Figure B).

-

for Hydrogen Index (HI) and S2peak, indicate that samples from the Neogene Itsmina and Conglomerados de laMojarra formations have poor generation potential (HI < 200mg HC/g TOC and S2 < 5

mg HC/g rock) but considering the high thermal maturity reached according to Tmaxdata, their present values could be evidence of organic content depletion, andsamples from the Paleogene Ir Formation have good to excellent generationpotential (HI > 200mg HC/g TOC and S2 > 5 mg HC/g rock).

The Tmax maturity parameter vs Hydrogen Index graph shows that most samplesfrom the Cenozoic units mentioned, have reached early maturity to overmaturegeneration conditions in the basin, being the samples from the Itsmina Formation the

most mature in the basin, and this high thermal maturity reached by these rockscould cause depletion in the organic content, giving low HI and S2 values.Considering this, it is very unlikely that these samples represent the real generationpotential of these formations in the basin (Figure C).

0 10 20 30 40 50 60 70 80 90 100

S2 (mgHC / gROCK)

0

100

200

300

400

500


Poor Generation Potential

and/or High thermal maturity


IR Fm.

UNKNOWN

CONGLOMERADOSDE LA MOJARRA Fm.

ISTMINA Fm.0 50 100 150 200 250 300


0

100

200

300

400

500

600


I I I

I I I

IV

370 390 410 430 450 470 490 510 530 550

Tmax (oC)

0

200

400

600

HydrogenIndex(mgHC/gTO

C)

III

III

1.35% Ro

0.5

%

Ro



A B

80 800


59/182

51 CHOC BASIN

LEGEND

- Organic content (%TOC) and S2 peak values indicate source rock oil generation potential, this graph shows that there are samplesfrom the Ir Formation with good to excellent oil generation potential (S2 up to 50 mg HC/g rock and % TOC up to 9) (Figure A).

- The Hydrogen Index vs Organic content (%TOC) graph shows that samples from the Ir Formation have the best source rockcharacteristics (HI values > 300 mg HC/g TOC and %TOC > 2), which are typical from rocks deposited in shelf marine environments.Again the low HI and %TOC values for the samples of the Itsmina Formation could be affected by the high thermal maturity reached bythis unit, and the data could not be

Atlas Geoquimico 2010

Documents

Transcript of Atlas Geoquimico 2010