Syllabus Master Repsol

Master in

Oil and Gas Exploration and Production

CSFR Mostoles, Madrid. September 2014 - July 2015

Index

Introduction Basic Overview Block Specialization Block Field Training Block Team Project Block

4 4 5 5

Basic Overview Block

6

Refreshment introductory courses Geology for engineers + math&physics for geoscientist Exploration Principles: Basin Analysis and Petroleum Systems Exploration Principles: Structural Geology Well Logging Drilling Engineering Geophysics Reservoir Geology and Characterization Reservoir Engineering Well Testing Reservoir Simulation Subsurface Production Technology Surface Production Technology Economic Evaluation Risk Analysis Offshore Structures Timetable

Specialization Block Petroleum Engineering (PE) Reservoir Evaluation and Management (REM) Petroleum Geosciences (PetGeo)

Petroleum Engineering Production Technologies Reservoir Engineering Well Test Analysis Reservoir Simulation Petroleum Economics

Reservoir Evaluation and Management Rock Mechanics, Geomechanics and Geophysics Well Testing and Production Logging Modeling and Management

Petroleum Geosciences Stratigraphy and Reservoir Quality Petroleum Systems Petroleum Geophysics Geomechanics and Flow Mechanics

Specialization Block Timetable

7 7 9 13 16 19 22 26 29 32 35 37 40 44 48 51 53

55 57 57 57

58 59 62 64 66

68 69 71 73

74 75 76 77 78

79

Field Training Block Geological Field School Drilling Field School Production Field School REPSOL HSE School

Team Project Block Use of real E&P data Objectives Multidisciplinary teams Assessment Technical software Tutorials Tutorials Competencies (Soft Skills) PROJECT Timetable

81 82 85 86 87

89 90 90 91 91 91 91 92 94 95

Master in Oil and Gas Exploration and Production Introduction This postgraduate program has been designed to train young professionals as their initial steps towards a career within Repsol in oil and gas exploration and production. It is aimed at university graduates from geosciences and/or engineering backgrounds, who recently joined or wish to join Repsol companies active in the E&P field, professionals from National Oil Companies, International Foundations invited by Repsol to the program, and personnel from other E&P companies under a cooperation Agreement with Repsol. The students should have an excellent basic technical background before joining the E&P Master at the Centro Superior de Formacion Repsol (CSFR). The education they receive during this Master Program will help them familiarize with the necessary tools and acquire key skills that will enable them to carry out their professional E&P activities in the most efficient way. Exploration and Production activities have a strong international character, thus the program in Madrid is fully and exclusively taught in English. CSFR teaching staff is composed by foreign university teachers and highly qualified petroleum industry professionals drawn mainly from Repsol. The second quarter of the program called Specialization Block is taught at Heriot-Watt University (Edinburgh, United Kingdom). The program lasts eleven months, starting on September 1st, 2014 and finishing on July 31st, 2015. It is structured in four blocks as they are described below: Basic Overview Block Its purpose is that the students reach a basic level of knowledge in all areas involved in Oil and Gas Exploration and Production activities. The methodology used is based on the following key points:  The block is divided into one week modules, which include basic theoretical concept.  Real case studies are carried out within each module.  Students’ performance is evaluated at the end of each module. This block weighs 35% of the final mark of the Master. There is a required minimum level of performance at BOB in order to continue on the Master program (please refer to the Students Handbook). Specialization Block Its purpose is to go in depth into specific areas of the disciplines involved in an E&P project (geology, geophysics and reservoir and petroleum engineering) according to the students' preferences and their previous academic qualifications. The students will be integrated into the relevant programs delivered by the Heriot-Watt University in Edinburgh (United Kingdom). Those who intend to specialize in Engineering (Production or Reservoir) will enter the MSc. in Petroleum Engineering or the MSc. in Reservoir Evaluation and Management Specialization. Those who intend to specialize in Geosciences will join the HWU’s students at the MSc in Petroleum Geosciences. This block will be evaluated in Madrid in examinations supervised by official HWU invigilators. The average of these examinations weights 35% of the final mark.

CENTRO SUPERIOR DE FORMACION REPSOL

4

Field Training Block Its purpose is to visualize in the Field most of the concepts learned in the previous Blocks. It involves three different areas to be covered:    

Geology Field School (takes place during the Basic Overview Block). Drilling Field School. Production Field School. HSE Field School and Formal Certifications

Some presentations could be required at the end of each Field School, and the participation and commitment during these weeks will be considered for approval of the Master Program. Team Project Block Its purpose is to apply the concepts learnt in the previous blocks while working in a multidisciplinary team on a project with specific objectives and within a prescribed schedule. The methodology includes:  Access to a database related to a real oil/gas field, which will be taken as a starting point.  Use the technical advanced software tools as within Repsol E&P.  Tutorial support provided by Repsol experts and external consultants.  Formal presentation of conclusions and results upon project completion to a Board of Experts composed by Repsol E&P Directors. The evaluation strategy will be explained further in detail. The final mark for this block weighs 30% of the final mark for the Master.

Overview Lecture period Instruction begins Closing ceremony Length Academic hours

September 2014 - July 2015 September 1st 2014 July 24th 2015 11 months ~1500

Terms and Holidays periods Period Basic Overview Block Christmas Holidays HWU Specialization Block HSE School Prod. & Drill Field Schools HWU Exams at CSFR HSE Certificates Final Project

Start date September 1st 2014 December 20th 2013 January 12th 2015 March 23rd 2015 March 30th 2015 April 13th 2015 May 11th 2015 May 18th 2015

Finish date December 19th 2014 January 8th 2015 March 20th 2015 March 27th 2015 April 10th 2015 May 8th 2015 May 15th 2015 July 17th 2015

* Schedule by January on subject to be changed based on HWU and Field Schools dates to be confirmed.


5

Master in Oil and Gas Exploration and Production

BLOCK I: BASIC OVERVIEW BLOCK CSFR Madrid September to December 2014

BASIC OVERVIEW BLOCK REFRESHMENT INTRODUCTORY COURSES

Module BOB 0

GEOLOGY FOR ENGINEERS + MATH&PHYSICS FOR GEOSCIENTIST

Geology for Non Geologists Lecturer Dr. Tomas Zapata holds a Ph.D. in Structural Geology from Cornell University USA, after graduating in Geology at University of Buenos Aires, where he was later Assistant Professor from 2001-2011. He also has a Business Administration degree from the Austral University of Argentina. Since 1996, he has conducted Exploration activities on technical and managerial positions, analyzing several basins throughout Latin America, focusing his studies on the Andean fold and thrust belt, where he participated on several oil and deep gas discoveries. He was a Structural Geology specialist for the Exploration study groups and he has published more than 40 papers on Structural Geology and Tectonics of the Andes. He is currently the Director of Geology of Repsol Exploración, and he manages the geological knowledge providing specific services to the E&P business units.

1 The Terrestrial Globe 1.1 Size and Composition of the Earth Interior 1.2 Age of the Earth. Geological Time Scale 2 Rock Types 2.1 Igneous 2.2 Sedimentary 2.3 Metamorphic 3 Sedimentary Rocks 3.1Nature and Origin of Sedimentary Rocks (Chemical & Mechanical Weathering, Transport, Deposition and Diagenesis) 3.2 Sedimentary Environments 3.3 Sedimentary Rock Classification 4 Stratification 4.1 Formations 4.2 Beds 4.3 The Facies Concept 4.4 Sedimentary Breaks & Unconformities 4.5 Transgretion/Regretion/Progradation 4.6 Sediments Dating 5 Structural Geology 5.1 Earth Tectonics 5.2 Faults Normal, Reverse, Listric Faults, Strike Slip, Horst, Graven 5.3 Fold System, Anticlne , syncline 5.4 Diapirsm

Mathematics & Physics for Non Engineers Lecturer Dr. Francisco Jose Mustieles joined Repsol Exploracion in 1998, as a Specialist in numerical simulation within the Reservoir Engineering Department. He received both a BSc degree (1985) and a PhD degree (1989) in Mining Engineering from ETSIM (UPM). In 1990, he received a PhD degree in Applied Mathematics from “École Polytechnique” in Paris. He was a lecturer in the School of Mines (ETSIM) in Madrid. In 1994, he joined the University “Alfonso X el Sabio”, in Madrid, where he led the Applied Mathematics Department. MATHEMATICS 1 Exponents and Roots 2. Logarithms 3. Analytic Geometry 3.1 Line Equation 3.2 Least Squares Fit to a Straight Line 3.3Graphs (Log-Normal Scale) 4 Functions 4.1 Equation Solving 5 Derivatives 5.1 Definition 5.2 Derivatives 5.3 Properties 6 Partial Differentiation PHYSICS 1 Physical Units Distance/Volume/Time/Speed/Acceleration/Volume/Mass/Density/Pressure/Flow Rate/Viscosity/Power 2 Unit Conversion 3 Energy 4 Fluid Mechanics 4.1 Poiseuille Law 4.2 Pressure losses for an incompressible fluid in a pipeline 4.3 Rheology 5 Gases Behaviour 5.1 Boyle´s Law 5.2 Charles Law 5.3 Avogadro´s Law 5.4 Equation of State for an Ideal Gas 5.5 Standard Conditions 5.6 Mole Fraction/ Daltons Law/Amagat Law/Apparent Molecular Weight/Specific Gravity

BASIC OVERVIEW BLOCK EXPLORATION PRINCIPLES: BASIN ANALYSIS AND PETROLEUM SYSTEMS

Module BOB 1B

Lecturers Mr. Santiago Quesada joined Repsol Exploracion in 1997, and since then he has served as Advisor Geologist for Geochemistry and Petroleum System Analysis in the Department of Technology. He holds a BSc. and a Postgraduate Degree in Geology from the University of the Basque Country (UPV). Mr. Quesada is an exploration geologist with 15 years of experience in basin analysis and evaluation of play concepts, prospects and leads; he is a specialist in Geochemistry and Petroleum System Modelling. Dr. Álvaro Racero graduated as Mining Engineer and got his PhD from the Polytechnic University of Madrid ETSIMM. His professional career started fist as operations geophysicist for Prakla before joining Shell International E&P in 1986 into the exploration division with international assignments in Netherland, Venezuela and Brunei. He moved into Repsol E&P in 2001 for the New Ventures Dpt. Repsol successively promoted him to Director of Exploration and Development for the Caribbean Region, Director of the North America Business Unit, both in Houston, and Regional Executive Director for E&P activities of Repsol in Europe Africa and Asia. In 2010, he was appointed as Repsol’s Regional Executive Director for the Caribbean and Northern Latin America and now he is the Executive Director of Technical Development for Repsol E&P. He has been a member of the Repsol E&P Directors Committee since 2006 Objectives To learn and understand the concepts and techniques of Petroleum Systems and Basin Analysis and their applications to petroleum exploration. 1. 2. 3. 4.

Learn the different levels of Petroleum Investigation. Understand the types and dynamics of sedimentary basins. Learn the concepts and applications of petroleum systems. Understand the geological elements and processes that make up a petroleum system. 5. Become familiar with concepts of geochemistry and their applications to petroleum exploration. 6. Learn the different computer techniques for petroleum system analysis. 7. Perform a computer-assisted petroleum system exercise with BasinMod to apply the concepts. Syllabus 1. Levels of Petroleum Investigation 1.1. Sedimentary Basins, Petroleum Systems, Prospects and Plays

2. Sedimentary Basins. 2.1. 2.2. 2.3. 2.4.

Mechanisms of Basin Formation Classification of Sedimentary Basins The Sedimentary Basin Fill Petroleum potential of different sedimentary basins


9

3. Petroleum Systems 3.1. 3.2. 3.3. 3.4.

Definition Geographical extension Elements and processes Timing and Critical Moment

4. Petroleum System Analysis and Modelling 4.1. Modelling Techniques and software 4.2. Backstripping and Forward Modelling 4.3. Modelling Work Flow

a) Geologic Inputs (Geologic Model) b) Geochemical Inputs (Geochemical Model) c) Thermal Inputs (Thermal Model) d) Simulations and Calibration e) Outputs 5. Geologic Model 5.1. Conceptual Model: Basin Characteristics and Geologic Elements 5.2. Lithostratigraphy and Chronostratigraphy: Unconformities 5.3. Source Rocks

a) Definition, types and quality (richness and source potential) 5.4. Reservoirs

a) Definition, types permeability)

and

properties

(geometry,

continuity,

porosity,

5.5. 5.4.- Traps

a) Definition and types (stratigraphic, structural, hydrodynamic etc.) 5.6. Seal

a) Definition, types and properties (seal efficiency, fracture gradient etc) 6. Geochemical Model: Organic Geochemistry of Petroleum and Source Rocks 6.1. Analytical Programs 6.2. Source Rocks

a) Composition: Kerogen and Extract b) Richness: TOC Analysis c) Source Potential: Pyrolysis Techniques d) Organic Matter Type: Kerogen Analysis e) Thermal Maturity: Vitrinite Reflectance, TAI, Tmax etc. 6.3. Crude Oil and Natural Gas

a) Composition: Hydrocarbon fractions and Non Hydrocarbons b) Bulk Properties: API, Sulfur Content, Pour Point, Wetness etc. c) Molecular Composition: GCMS Analysis and Biomarkers d) Isotopes e) Correlation studies 7. Thermal Model 7.1. Geothermal Gradient 7.2. Heat Flow: Definition, types and sources 7.3. Thermal Conductivity of rocks

8. Modelling Burial History 8.1. 8.2. 8.3. 8.4. 8.5.

Construction of Chronostratigraphic Charts Compaction: Definition and methods Integration of porosity data Calibration Construction and interpretation of Burial History Graphs

9. Modelling Thermal Maturity


10

9.1. 9.2. 9.3. 9.4.

Present day Heat Flow and Heat Flow History Integration of Thermal Data and Maturity Indicators Calibration Interpretation of maturity results

10. Modelling Generation and Expulsion of Hydrocarbons 10.1. Oil and Gas formation and destruction: Primary and Secondary Cracking 10.2. Kinetic equations: Theory and application 10.3. Interpretation of results

11. Review of Migration concepts 11.1. Factors controlling migration 11.2. Migration mechanisms: lateral, vertical 11.3. Migration models and equations

Main Exercises and Tutorials  Exercise 1: Maturity Model.  Exercise 2: Exploration Process, from Play Concept to Discovery. Program This course lasts 5 days Day 1    

Levels of Petroleum Investigation Sedimentary Basins. Petroleum Systems Petroleum System Analysis and Modelling

Day 2  Geologic Model  Geochemical Model: Organic Geochemistry of Petroleum and Source Rocks  Thermal Model Day 3    

Modelling Burial History Exercises Modelling Thermal Maturity Basin Mod Exercise begins

Day 4  Modelling Generation and Expulsion of Hydrocarbons  Basin Mod Exercise continue Day 5  Review of Migration concepts  Discussion of Modelling Results  Summary and Conclusions Software Applications  BasinMod 1D. CENTRO SUPERIOR DE FORMACION REPSOL

11

Textbooks and Consulting Books  “Elements of Petroleum Geology” Richard C. Selley, Academic Press. 1998.  “Petroleum Geochemistry and Geology” John M. Hunt, W.H. Freeman. 1996.  “Applied Subsurface Geological Mapping” D. J. Tearpock and R.E. Bischke, Prentice Hall. 1991.


12

BASIC OVERVIEW BLOCK Module BOB 1C

EXPLORATION PRINCIPLES: STRUCTURAL GEOLOGY Lecturer Dr. Alan Chambers has 21 years oil industry experience with Mobil Oil, Union Texas Petroleum and Repsol Exploracion. Previously, he was awarded his doctorate in Structural Geology (Imperial College, London) for his research into Himalayan thrust belt evolution. Dr. Chambers is a specialist in Structural Geology, and has broad experience in petroleum exploration projects. He is currently assigned to Regional Exploracion (ME-CIS) in Dubai, UAE. Objectives To introduce the basic concepts of structural geology and the hydrocarbon trap. 1. 2. 3. 4. 5. 6. 7.

To understand the Theory of Plate Tectonics. To understand the Process of Rock Failure. To understand the factors required to produce the Hydrocarbon Trap. To recognize the main Extensional Trapping Styles. To recognize the main Strike-Slip Trapping Styles. To recognize the Contractional Trapping Styles. To introduce the main Stratigraphic Trapping Styles.

Syllabus 1. The Theory of Plate Tectonics. 1.1. Continental Drift. 1.2. Seafloor Spreading. 1.3. Plate Tectonic Theory and Types of Plate Margin. 1.4. Intra-cratonic Deformation and Crustal Stress.

2. An Introduction to Rock Mechanics and Rock Failure Modes. 2.1. Andersonian Principles. 2.2. Mohr Circles. 2.3. Coulomb-Navier Failure. 2.4. The Effect of Pore Pressure. 2.5. Neotectonics.

3. Contractional Tectonics. 3.1. Thin-skinned Deformation (terminology, detachments, wedge theory, controls, evaporites). 3.2. Thick-skinned Deformation (basement involvement, pre-existing weaknesses). 3.3. Seismic Expression. 3.4. Field Examples.

4. Strike-Slip Tectonics. 4.1. Basic Terminology. 4.2. Contractional Pop-Ups 4.3. Extensional Pull-Aparts. 4.4. Seismic Expression. 4.5. Field Examples.

5. Extensional Tectonics.


13

5.1. Rift Basins. 5.2. Subsidence History. 5.3. Fault Growth, Fault Linkage and Fault Seal. 5.4. Rift Inversion. 5.5. Seismic Expression. 5.6. Field Examples.

6. Gravitational Tectonics. 6.1. Rheologically weak layers and salt. 6.2. Linked Extensional-Contractional Systems. 6.3. Delta Systems, confined and unconfined depositional processes. 6.4. Seismic Expression.

7. Stratigraphic Traps. 7.1. Stratigraphic Pinch-out. 7.2. Truncation. 7.3. Carbonate Build-Ups and Ramps. 7.4. Diagenetic Trapping Processes. 7.5. Hydrodynamic Trapping Processes.

8. Prospect Mapping. 8.1. Seismic Interpretation of Horizons. 8.2. Seismic Interpretation of Faults. 8.3. Generating a Two-Way-Time Contour Map with Faults. 8.4. Quicklook Volume Estimation. 8.5. An Introduction to Geologic Risk and Prospect Ranking.

Main Exercises and Tutorials  Exercises 1-8: Seismic Interpretation of Classic Structural Styles.  Exercise 9: Seismic Interpretation of Multiple 2D Seismic Lines in an Extensional Setting. Program This course lasts 5 days. Day 1:  Plate Tectonics.  Rock Failure. Day 2:  Contractional Tectonics & Trapping Geometries. Day 3:  Strike-Slip Tectonics & Trapping Geometries.  Gravitational Tectonics and Trapping Geometries. Day 4:  Extensional Tectonics and Trapping Geometries. Day 5:  Stratigraphic Trapping Geometries.  Module Exam.


14

Software Applications  Microsoft Office. Textbooks and Consulting Books     

Essentials of Geology; 10th edition, by Lutgens & Tarbuck. Essentials of Geology; 3rd edition, by Marshak. Earth: An Introduction to Physical Geology; 9th edition, by White. Thrust Tectonics; by Ken McClay. Sedimentation and Tectonics in Rift Basins; by Purser & Bosence.


15

BASIC OVERVIEW BLOCK Module BOB 3

WELL LOGGING Lecturers Mr. Stephen Winstanley has more than 26 years’ experience working in the E&P industry. He graduated with a B.Sc. Joint Honours in Geography and Geology from Manchester University, England in 1984. Between 1985 and 1998 he worked as a Petrophysicist for a number of Consultancy’s including Scientific Software-Intercomp, Robertson Research and Ikoda. In 1998 he joined Anadarko Algeria Corporation and worked rotation out of the Algerian Sahara and was a Senior Petrophysicist responsible for all exploration, development and cased hole Petrophysical support to a dozen producing Fields. In 2005 he re-located to Houston with Anadarko Petroleum Corporation as Petrophysical Advisor working with the Gulf of Mexico Exploration Team during a phase when several large Miocene and Eocence discoveries were made. In 2010 he was made Manager of U.S. Onshore Petrophysics and oversaw the increasing role of Petrophysics in unconventional and non-conventional plays such as the Marcellus, Bone Springs, Eagleford, Avalon Shale, Wolfcamp and Onshore Louisian Eocene. In 2011 he joined Repsol USA as Senior Petrophysical Advisor and has worked with the U.S. Business unit on the Alaska Exploration and Mississippi Lime projects. He currently works with the North America and Brazil Reservoir Development team and provides Petrophysical support for projects as diverse as Pao de Azucar and Carioca (Brazil) reservoir development, offshore Peru exploration and Canada exploration as well as contributing to the Reservoir Characterization Manual.

Objectives 1. Rock Recognition / Lithology. 2. Rock Properties calculation. 3. Fluids & contacts (OWC, GWC & GOC). Syllabus 1. Course Outline and Objectives; Nature of a Hydrocarbon Accumulation; Porosity, Permeability, Wetness and the Matrix Concept; Invasion; Acquisition and Recording of Wireline Log Data; Nomenclature and Types of Logs. 2. Wireline Open Hole Tools and Services. The Electric Logs and SP and their Interpretation; The Sonic Log and its Interpretation; The Radioactive Logs and their Interpretation; Qualitative Interpretation of Logs, Litho logy Determination and Gas Detection. 3. Quantitative Interpretation: Introduction and Objectives; Shale and Hydrocarbon Correction; Effective Porosity; Formation Factor; Rw Sw and Sxo Determination; Estimation of the Depth of Mud Filtrate Invasion; Evaluation of a Clean Sandstone Reservoir and Carbonate Reservoir.


16

Main Exercises and Tutorials     

Exercise 1: Qualitative Interpretation. Exercise 2: Lithology and Porosity Identification. Exercise 3: Quantitative Interpretation: Rw, Sw and Sxo Determination. Exercise 4: Evaluation of a Clastic Gas Bearing Reservoir. Exercise 5: Evaluation of a Carbonate Reservoir.

Program        

Basic Log Interpretation Concepts. Invasion Profiles. Resistivity as a Basis for Interpretation: The Archie equation. Porosity Models. Acquisition and Recording of Wireline Logs. Formation Resistivity. The SP. Resistivity Tools: - Laterolog. - Induction. - DIL / DLL / MSFL. - AIT / ARI.

 Qualitative exercise.  Nuclear Tools: - GR / NGT. - Density / Pef. - Neutrons.

              

Qualitative exercise. Sonics. Qualitative exercise. Cross plots Analysis: Porosity - Lithology. Rw Determination Methods. Sw determination. Gas Corrections - Clean Sands. Shaly Sand Interpretation. Vsh Determination. Quantitative Exercises. Qualitative Exercises. Evaluation of a Sand Reservoir. Evaluation of a Carbonate Reservoir. Evaluation of a Clastic Gas-bearing Reservoir. Evaluation Consolidation. CENTRO SUPERIOR DE FORMACION REPSOL

17

Software Applications  Microsoft Office. Textbooks and Consulting Books  “Log Interpretation Principles / Applications”. Schlumberger. 1989.  “Log Interpretation Charts”. Schlumberger. 1998.  “Fundamentals of Well Logs Interpretation 1, 2”. O. Serra, Elsevier. Amsterdam 1984.  “Logging While Drilling”. Schlumberger. 1993.


18


DRILLING ENGINEERING Lecturer Dr. John Ford joined the Dept. of Petroleum Engineering in Heriot-Watt University as Senior Lecturer in June 1998. He received a BSc. Honours degree in Civil Engineering from University of Newcastle Upon Tyne and a MSc. in Petroleum Engineering degree and a PhD from Heriot-Watt University. He spent several years employed by Shell International Petroleum Co. Ltd, as a Drilling Engineer, in Brunei, Tunisia and Holland. Objectives This is an introduction to Drilling Engineering. The objectives are to introduce the concepts and equipment used in drilling; to examine the design requirements and techniques and to examine the optimization of the drilling activity. Syllabus 1. Introduction 2. Overview 3. Rig Components 4. Drill String 5. Bits 6. Formation Pressure 7. Hydraulics 8. Well Control 9. Drilling Fluids 10. Casing 11. Cementing 12. Directional Drilling 13. Directional surveying 14. MWD 15. Offshore Drilling Program Day 1     

Overview of Drilling. Rig Components. Bits. Film: Rotary Rig. Exercises: - Bit Selection and Grading. - Start Drilling program. - Start Equipment List/Rig Spec.


19

Day 2    

Drilling Fluids, Hydraulics. Formation Pressures. Casing Introduction. Exercises: - LOT Evaluation.

 Drilling Program: - Select Drilling Fluids.

Day 3  Drilling Program: - Start Casing Design. - Start Logistics Program. - Casing Design (Cont.)

 Cementing. Day 4  Well Control. - Film: Well Control.

 Exercises: - LOT Evaluation. - Drilling Program. - Casing Design/Program. - Cementing Design.

 Tutorials: Drilling Office.  Well Control. Day 5  Directional Drilling and Surveying. - Film: Directional Drilling.

 Well Control, Directional Design, Survey.  Evaluation Exercises. Main Exercises and Tutorials        

Bit Selection and Grading Drilling Program (Drilling fluids and casing design) Rig Specifications LOT Evaluation Casing Program Cementing Program Well Control Directional well design and surveying


20

Textbooks and Consulting Books    

“Drilling Data Handbook”, Ed. Technip - IFP. Halliburton Table. “Field Data Handbook”. Dowell Schlumberger. “IADC Drilling Manual”. “Petroleo Moderno: Un manual básico para la Industria”. Bill D. Berger, January 1999. PennWell Publishing Co. ISBN 0-87814-755-1.  “Fundamentals of Casing Design”. H. Rabia. ISBN 0-86010-863-5.  “Kicks and Blowout Control”. Adams and Kuhlman. ISBN-87814-419-6.


21


GEOPHYSICS Lecturer Mr. Cristi Constantin Lupascu joined Repsol in 2009 as a Senior Geophysical Advisor for Subsurface Imaging - Geophysical Technology Group in Houston. His current assignment is Head of Repsol Data Processing Center - Geophysics Upstream in Madrid. He holds a Master Degree in Geophysics from the University of Bucharest and he has started his career 25 years ago in Romania, with Geomold SA Geological and Geophysical Exploration. As part of a 3DGeo Development Houston team, he was the recipient of 2007 Hart's E&P Special Meritorious Award for Engineering Innovation for “Imaging Ultra Deep Structures using Wave Equation Migration and Illumination”. His last assignment before joining Repsol was with Fusion Petroleum, Houston USA, as Seismic Imaging and Operations Manager. Objectives 1. Become acquainted with the main geophysical methods used in exploration, their applications and their limitations. 2. Understand the basic concepts of seismic wave propagation, reflection, diffraction and refraction. 3. Understand in broad terms how 3D-seismic land and marine data are acquired. 4. Understand in broad terms how seismic data is processed. 5. Understand how seismic data can be linked to geology by using well data. 6. Learn how seismic data can be converted from time to depth. 7. Get to know how 2D-seismic data is interpreted and how horizon maps are made. 8. Learn how 3D-seismic data is interpreted. How horizon maps are made, the principle of attribute extraction. Syllabus 1. Introduction to Geophysics. 1.1. 1.2. 1.3. 1.4. 1.5. 1.6. 1.7. 1.8. 1.9.

The Objective. The Limitations. Inversion of Data. The Importance of Different Survey Methods. The Gravity Method. The Magnetic Method. The Basic Seismic System. The Seismic Objective. The Role of Seismology in Hydrocarbon Exploration.

2. Seismic Waves. 2.1. 2.2. 2.3. 2.4. 2.5. 2.6.

Reflections. Diffractions. Refractions. Ground-Roll. Multiples. Reflection Coefficient.

3. Data Acquisition.


22

3.1. 3.2. 3.3. 3.4. 3.5. 3.6. 3.7. 3.8.

Seismic Sources. Seismic Receivers. Seismic Spreads. Key Parameters in 3D-Seismic Acquisition. Logistics of Land Acquisition. Logistics of Marine Acquisition. Acquisition Time. Acquisition Cost.

4. Data Processing 4.1. 4.2. 4.3. 4.4. 4.5.

Processing Objective. Main Processing Steps. Interpretive Elements in Seismic Processing. Processing Time. Processing Cost.

5. The Link between Seismic and Well Information. 5.1. 5.2. 5.3. 5.4. 5.5.

Overview Well Calibration. Well Shooting. Sonic and Density Logs. Synthetic Seismograms. Problems and Pitfalls in Seismic Calibration with Well Data.

6. Time to Depth Conversion. 6.1. 6.2. 6.3. 6.4. 6.5. 6.6.

Overview Depth Conversion. Velocity Information. Depth Conversion Methods. Limitations of the Various Methods. Strong Lateral Velocity Variations. Problems and Pitfalls in Depth Conversion.

7. 2D and 3D Seismic Interpretation 7.1. 7.2. 7.3. 7.4. 7.5. 7.6.

The Seismic Interpretation Objective. Identification and Interpretation of Geologic Horizons. How to Create a Horizon Map. Fault Interpretation in 2D and 3D. Problems and Limitations of 2D Seismic Interpretation. 3D Seismic Interpretation.

8. Seismic Attributes. 8.1. 8.2. 8.3. 8.4. 8.5. 8.6. 8.7.

The Meaning of Seismic Attributes. Different type and use of Seismic Attributes. Lithology and fluid Reservoir Analysis. Shallow Hazards. Pore Pressure Prediction. Fractures and Anisotropy. Cases Histories examples.

Main Exercises and Tutorials    

Various simple exercises. Well calibration. Depth conversion. Seismic Modelling.


23

Program This course lasts 5 days. Day 1:    

Introduction to the course module. Introduction to Geophysics. Seismic Waves & Ray Theory. Exercises.

Day 2:      

Data acquisition (with video). Sampling Theory. Filtering Theory. Seismic Data Acquisition. Seismic Data Processing. Exercises.

Day 3:     

Seismic Data Processing (cont.) VSP seismic. Sonic and density logs. Synthetic Seismograms. Exercises.

Day 4:      

Structural Interpretation. Stratigraphic Interpretation. Seismic Attributes. AVO, Inversion. Seismic Modelling. Exercises.

Day 5:    

Course review. Exercises. Discussion of result of exercises. Final Test.


24

Textbooks and Consulting Books  Avseth, P., Mukerji, T., and Mavko, G. Quantitative seismic interpretation: Applying rock physics tools to reduce interpretation risk, Cambridge University Press, 2006, ISBN 9780521816014.  Brown A.: Interpretation of Three-Dimensional Seismic Data: AAPG Memoir 42, Fifth Edition. 1999. ISBN 0-89181-352-7.  J. P. Castagna, J.P. and M. Backus: Theory and practice of AVO analysis. Investigations in Geophysics No. 8, 1993.  Hilterman, F. J.: Seismic amplitude interpretation: Society of Exploration Geophysics. SEG distinguished instructor short course, No. 4.  Labo J.: A Practical Introduction to Borehole Geophysics: Society of Exploration Geophysicists (SEG), Tulsa Oklahoma. 1992. ISBN 0-931830-39-7.  McQuillin R., Bacon M., Barclay W.: An Introduction to Seismic Interpretation: Graham & Trotman Ltd. 1984. ISBN 0-86010-496-6.  Nettleton, L.L. Gravity and Magnetics in Oil Prospecting, McGraw Hill, 1976.  Schlumberger: Log Interpretation Principles/Applications: Schlumberger Educational Services, Houston, Texas, Order No. SMP-7017. 1991.  Sheriff R.E.: Encyclopaedic Dictionary of Exploration Geophysics, Third Edition: Society of Exploration Geophysicists (SEG), Tulsa Oklahoma. 1991. ISBN 1-56080018-6.  Stone D. G.: Designing Seismic Surveys in Two and Three Dimensions: Society of Exploration Geophysicists (SEG), Tulsa Oklahoma. 1994. ISBN 1-56080-073-9.  Yilmaz Ö.: Seismic Data Processing: Society of Exploration Geophysicists (SEG), Tulsa Oklahoma. 1987. ISBN 0-931830-40-09.


25

BASIC OVERVIEW BLOCK Module BOB 6A

RESERVOIR GEOLOGY AND CHARACTERIZATION Lecturer Dr. Patrick Corbett is Professor of Petroleum Engineering in the Petroleum Engineering Department at Heriot-Watt University (Edinburgh). He received an Honours BSc. Geology degree from Exeter University, MSc Micropalaeontology degree from University College, London, and PG Dip (Distinction) degree in Geological Statistics from Kingston Poly. (PT) and Doctor of Philosophy degree in Petroleum Engineering from Heriot-Watt University. After spending several years in Gearhart-Owen, Union Oil GB, Unocal Netherlands and Unocal Indonesia he joined Heriot-Watt University in 1989. Mr. Javier Prieto has more than 21 years´ experience working on the E&P industry. He graduated as Bachelor Geological Science in Oviedo University, Spain. He is currently Sr. Reservoir Geologist in the Reggane Nord Project, Argelia, and he has worked for Repsol E&P as reservoir geologist in Libya oilfields and also different development projects in Venezuela, Argentina, Ecuador and Madrid. Objectives 1. Become acquainted with the controls of deposition on the properties and geometries of reservoirs. 2. Get to know how to recognize reservoir flow units. 3. Learn how to define the flow unit geometry in the subsurface. 4. Learn how to draw maps of flow units. 5. Learn how to define properties of flow units. 6. Learn how to determine volumetric hydrocarbons in place. Syllabus 1. Sedimentology. 1.1. 1.2. 1.3. 1.4.

Texture and properties – clastics. Fluvial reservoirs – geometries. Shallow marine reservoirs – geometries. Deep water reservoirs – geometries.

2. Correlation. 2.1. 2.2. 2.3. 2.4. 2.5. 2.6. 2.7.

Introduction. Stratigraphy. Correlation panels and cross sections. Stratigraphy and reservoir performance. Architecture, drive mechanism and recovery. Compartmentalization and reserves. Tutorial.

a) Layercake reservoir correlation. b) Jigsaw reservoir correlation. c) Casablanca reservoir correlation. 2.8. Supplement.

a) Sequence stratigraphic concepts. b) Geobodies and outcrops. c) Scale of geological elements. CENTRO SUPERIOR DE FORMACION REPSOL

26

3. Mapping. 3.1. Introduction. 3.2. Data types. 3.3. Manual contouring. 3.4. Computer contouring. 3.5. Structural maps. 3.6. Determination of Gross Rock Volume. 3.7. Isopachs. 3.8. Grid manipulation. 3.9. Fault maps. 3.10. Tutorial.

a) Mapping exercise. b) GRV determination in Casablanca Field. 4. Geological statistics. 4.1. 4.2. 4.3. 4.4. 4.5. 4.6. 4.7.

Introduction. Measures of central tendency. Measures of variability. Distributions. Sample sufficiency. Measures of spatial correlation. Tutorials.

a) Averages. b) Heterogeneity. c) Variograms. 5. Volumetric. 5.1. 5.2. 5.3. 5.4. 5.5. 5.6. 5.7.

Introduction. Gross reservoir and Net Pay. Deterministic HIP calculations. Monte Carlo HIP calculations. Reserves definitions and categories. Handling Uncertainty. Tutorials.

a) Reserve determination exercises. b) Monte Carlo reserves – Casablanca Field. 6. Reservoir Static Modelling. 6.1. 6.2. 6.3. 6.4.

Structural Framework. Reservoir Correlation and Zonation. Gridding Design. Facies modelling / Petrophysical Property modelling.

Main Exercises and Tutorials         

Layercake reservoir correlation. Jigsaw reservoir correlation. Casablanca reservoir correlation. Mapping exercise. GRV determination in Casablanca Field. Calculating Averages. Calculating Heterogeneity measures. Calculation of Variograms. Reserve determination exercises.


27

 Monte Carlo reserves - Casablanca Field. Program This course lasts 5 days. Day 1:  Sedimentology of reservoirs – deep water and fluvial. Day 2:  Correlation. Day 3:  Mapping. Day 4:  Geological Statistics. Day 5:  Volumetric. Textbooks and Consulting Books  Abbotts, I.L., 1991, UK Oil and Gas Fields, 25years Commemorative Volume, Geological Society, 573p.  Cosentino, L., 2001, Integrated reservoir Studies, Editions Technip, Paris, 310p.  Dubrule, O., 1998, Geostatistics in Petroleum Geology, AAPG Continuing Education Course Note Series #38, Tulsa, Oklahoma.  Jensen, J.L., Lake, L.W., Corbett, P.W.M., and Goggin, D.J., 2000, Statistics for Geoscientists and Engineers, Elsevier.  Morton-Thompson, D., and Woods, A.M., 1992, Development Geology Reference Manual, AAPG Methods in Exploration Series, 10, AAPG, Tulsa Ok, 550p.


28

BASIC OVERVIEW BLOCK Module BOB 6B

RESERVOIR ENGINEERING Lecturer Mr. Manuel Prida has 30 years of experience in the oil industry occupying several positions mainly related to Reservoir Engineering within Repsol. He graduated as Mining Engineer from the ETSIMO (1981); Master in Petroleum Engineering H.K. Van Poolen (1982); Master in Numerical Simulation from the Polytechnic University of Madrid (1991); and Economist from the UNED (2006). He is currently acting as Reservoir Department Manager of Business Development in the Repsol’s headquarters, Madrid. Initially, he was dedicated to the well testing and evaluation of exploration wells in Spain and worldwide. He also participated in several integrated reservoir studies, development projects, underground gas storage projects, and reserves acquisitions evaluations in several countries. He was international expatriate in Egypt and Libya, from 1994 to 2000. Upon his return to Repsol headquarters he was assigned to business development activities. Objectives 1. Understand Reservoir Rock Properties: Porosity, Permeability and Saturation. 2. Understand Reservoir Pressure and Temperature Regimes and the techniques used for Distributed Pressure Measurements. 3. Understand the Phase Behaviour of Reservoir Fluids. 4. Understand Reservoir Production Mechanisms. 5. Become acquainted with the Material Balance Technique. 6. Understand Waterflooding. Syllabus 1. Reservoir Rock Properties. 1.1. 1.2. 1.3. 1.4. 1.5. 1.6.

Porosity. Absolute Permeability (Darcy’s Law). Saturations. Capillary Pressure and Pore Size Distribution. Wettability. Effective and Relative Permeabilities.

2. Reservoir Pressure and Temperature. 2.1. Reservoir Fluid Pressure and Temperatures Regimes. 2.2. Techniques for Pressure Measurements: WFT.


29

3. Phase Behaviour of Reservoir Fluids. 3.1. 3.2. 3.3. 3.4.

Pure Substances. Multicomponent Hydrocarbon Mixtures. Pressure-Temperature Phase Diagram Classification of Reservoirs. Oil PVT Analysis:

a) Definition of the Basic Parameters (Bo, Rs, Bg) and their Evolution with Pressure. b) Oil Viscosity. c) Black Oil Correlations. d) Sampling Methods (Subsurface and Surface Recombined Samples). e) Laboratory Experiments (Flash Expansion, Differential Liberation, Separator Tests). 3.5. Gas and Gas-Condensate:

a) Ideal Gases. b) Behaviour of Real Gases: Equation of State. c) Definition of the Basic Parameters (Z, Eg, CGR) and their evolution with Pressure. d) Gas Viscosity. e) Correlations. f) Sampling Methods. g) Laboratory Experiments (Retrograde Condensation). h) Vapour Liquid Equilibrium Calculations: Equations of State. 3.6. Properties of Formation Waters.

4. Production Mechanisms. 4.1. 4.2. 4.3. 4.4. 4.5.

Radial Flow in a Porous Media. Reservoir Drives and Production Mechanisms. Primary, Secondary and Improved Oil Recovery. Recovery Factors. Reserve Determination and Classification.

5. Material Balance. 5.1. General Form of the Material Balance Equation. 5.2. The Material Balance Expressed as a Linear Equation. 5.3. Material Balance Applied to Oil Fields:

a) Depletion above Bubble Point. b) Solution Gas Drive. c) Gas-Cap Drive. d) Compaction Drive. e) Natural Water Drive. 5.4. Water Influx Calculations:

a) Hurst and Van Everdingen (Unsteady State). b) Fetkovitch. c) Carter-Tracy. 5.5. Gas Material Balance:

a) Volumetric Depletion. b) Natural Water Drive. 5.6. Limitations of the Material Balance.

6. Waterflooding Fundamentals. 6.1. 6.2. 6.3. 6.4. 6.5.

Rock Relative Permeabilities. Mobility Ratio. Fractional Flow. The Buckley Leverett One Dimensional Theory. Oil Recovery Calculations (Welge Technique).


30

Main Exercises and Tutorials       

Determination of the HWC from a WFT Survey. Understanding a Black Oil Lab. PVT Report. Converting Differential Liberation Data to obtain PVT Parameters. Using Tuned Black Oil Correlations to obtain a Full Reservoir Fluid description. Undersaturated Oil Material Balance. Gas Volumetric Material Balance. Oil Recovery Calculation.

Program This course lasts 5 days. Day 1:  Reservoir Rock Properties.  Reservoir Pressure and Temperature. Day 2:  Phase Behaviour of Reservoir Fluids: Oil, Gas, Water. Day 3:  Production Mechanisms. Day 4:  Material Balance Applied to Oil and Gas Reservoirs. Day 5:  Waterflooding: Fundamentals.  Course Final Test. Textbooks and Consulting Books  “Fundamentals of Reservoir Engineering”. L. P. Dake, 1978. Developments in Petroleum Science, 8. Elsevier.  “The Practice of Reservoir Engineering”. L. P. Dake, 1994. Developments in Petroleum Science, 36. Elsevier.  “Reservoir Fluids: The Properties of Petroleum Fluids”. W. D. McCain, 1990. Second Edition. PennWell.  “PVT and Phase Behaviour of Petroleum Reservoir Fluids”. Ali Danesh, 1998. Developments in Petroleum Science, 47. Elsevier.  “Waterflooding: The Reservoir Engineering Aspects of Waterflooding, Vol. 3”. F.F. Craig Jr., Third Printing 1993. SPE Reprint Series.  “Applied Petroleum Reservoir Engineering. Second Edition”. B. C. Craft, M. F. Hawkins, 1991. Prentice-Hall.  “Basics of Reservoir Engineering”. R. Cosse, 1993. Editions Technip.  “Petroleum Engineering Principles and Practices”. J. S. Archer. And C. G. Wall, 1986. Graham & Trotman.  “Petroleum Reservoir Engineering”. Amyx, Bass & Whiting. Mc Graw-Hill Book Company. CENTRO SUPERIOR DE FORMACION REPSOL

31

BASIC OVERVIEW BLOCK WELL TESTING

Module BOB 6D Lecturer

Ms. Elena Izaguirre is Head of Reservoir Engineering Technology in Repsol. She received a Mining Engineering degree from ETSIM (UPM). She has been working for Repsol VP Upstream since 1990 and has over sixteen years of experience in reservoir engineering. She has participated in technical assessment of new developments, reserves acquisitions and reservoir management of assets, in Spain and Algeria. Objectives 1. Become acquainted with Well Testing Data Acquisition and Interpretation Techniques. 2. Understand the basic theory of well testing. 3. Be able to design a well test. 4. Get to know the tools needed to implement a well test. 5. Understand a well test report. 6. Be able to recognize different well-reservoir models in a pressure derivative response. 7. Understand the differences between oil and gas well testing. 8. Be able to interpret a well test flow period in terms of reservoir properties and boundary conditions using PanSystem. Syllabus 1. Fundamentals: 1.1. 1.2. 1.3. 1.4. 1.5.

Darcy’s Law and its Applications. Fluid and Pore Isothermal Compressibility. Radial Diffusivity Equation and its Solution for Monophase Fluid Flow in Porous Media. Outer Boundary Conditions Transient (Infinite), Semi Steady State and Steady State. Superposition in Time and Space.

2. Well test Design and Execution: 2.1. 2.2. 2.3. 2.4. 2.5.

Objectives. Types of Tests. Downhole and Surface Equipment. Pressure Gauges and Rate Measurements. Sampling of Produced Fluids.

3. Basic well test Interpretation: 3.1. 3.2. 3.3. 3.4. 3.5.

Methodology. Techniques: Pressure Derivative, Type Curve Matching, and Specialized Plots. Early Time Near Wellbore Effects: WBS, Dimensionless Skin Factor. Radial Homogeneous Flow: Determination of Reservoir Parameters (k, S). Late Time Boundary and Depletion Effects:

a) Single Fault. b) Intersecting Faults. c) Linear Flow (Channel Sands and Parallel Faults).


32

d) Constant Pressure Boundaries. e) Closed Reservoirs. 4. Gas Well Testing: 4.1. Pseudo Pressure and Time. 4.2. Non-Darcy Flow. 4.3. Deliverability Tests.

5. Naturally Fractured Reservoirs: 5.1. Reservoir properties: geometry, porosity and capacity. 5.2. Matrix-fracture exchange. 5.3. Analysis of flow.

6. Artificially fractured wells: 6.1. Description of the fracture. 6.2. Flows around an artificially fractured well.

Main Exercises and Tutorials  Understanding a well test Report.  Interpretation of the pressure build-up of an Undersaturated Oil.  Oil and Gas well test Interpretations exercises using PanSystem. Program This course lasts 5 days. Day 1:  Fundamentals.  Well testing Design and Execution.  Tutorial 1. Day 2:  Basic well test Interpretation.  Tutorial 2. Day 3:    

Basic well test Interpretation (cont’). Tutorial 2 (cont’d). Gas well testing. Tutorial 3.

Day 4:    

Naturally fractured reservoirs. Tutorial 3 (cont’d). Artificially fractured well. Tutorial 3 (cont’d).

Day 5:  Course Examination.


33

Textbooks and Consulting Books  “Well Testing: Interpretation Methods“. G. Bourdarot, 1998. Editions Technip.


34

BASIC OVERVIEW BLOCK Module BOB 6E

RESERVOIR SIMULATION Lecturer Dr. Francisco Jose Mustieles joined Repsol Exploracion in 1998, as a Specialist in numerical simulation within the Reservoir Engineering Department. He received both a BSc degree (1985) and a PhD degree (1989) in Mining Engineering from ETSIM (UPM). In 1990, he received a PhD degree in Applied Mathematics from “École Polytechnique” in Paris. In 1990, he joined Telefonica, R&D, as responsible of numerical simulation tools. He was a lecturer in the School of Mines (ETSIM) in Madrid. In 1994, he joined the University “Alfonso X el Sabio”, in Madrid, where he led the Applied Mathematics Department. Objectives 1. To understand the role of numerical reservoir simulation in the context of reservoir economic development. 2. To understand the fluid flow equations in a porous media. 3. To understand the differences between compositional and black-oil model equations. 4. To understand the numerical discretization of fluid flow equations. 5. To grasp the general structure of an Eclipse Input Data File. 6. To be able to use Eclipse 100. Syllabus Part I: Reservoir Simulation Overview. 1. Introduction to Reservoir Simulation. 1.1. 1.2. 1.3. 1.4.

Purpose and benefits of numerical reservoir simulation. Relationship with other E&P matters. Main steps in the construction of a Reservoir Simulation Model. Types of Reservoir Simulation Models.

2. The Fluid Flow Equations in a Porous Media. 2.1. Continuity or Mass Conservation Equation. 2.2. Darcy’s Law. 2.3. Compositional and Black Oil Model Equations.

3. Numerical Discretization of the Fluid Flow Equations. 3.1. Notions about Finite Differences. 3.2. Types of Numerical Schemes:

a) IMPES. b) Fully Implicit. c) Streamlines. 3.3. Comments about numerical stability and accuracy.

Part II: Tutorial on General Structure of an Eclipse Input Data File. Case Study: Basic vertical cross-section model to estimate vertical sweep efficiency under Waterflooding for an Undersaturated oil reservoir.


35

Part III: Tutorial on Practical Use of Reservoir Simulation. Case Study: 3D Full Field simulation model for a real reservoir. - Data gathering. - Geological model. Grid construction. - Fluid and rock-fluid properties. - Aquifer modelling. - Initialization. - Well description. - History matching. - Forecast simulations.

Main Exercises and Tutorials  Basic exercises about finite difference discretization.  Modify and run with Eclipse 100 a vertical cross-section model to estimate sweep efficiency under waterflooding for an undersaturated oil.  Analyse input data and results of a 3D full field simulation model with different Pre and Post-Processors. Program Day 1  Reservoir Simulation Overview. Days 2-3  Tutorial on General Structure of an Eclipse Input Data File. Days 4-5  Tutorial on Practical Use of Reservoir Simulation. Software Applications  Eclipse 100.  Eclipse Office, Graf, Floviz. Textbooks and Consulting Books  Principles of Applied Reservoir Simulation. Fanchi, J.R.; Gulf Publishing Company. 2001.  Fundamentals of Numerical Reservoir Simulation. Peaceman, D.W.; Elsevier. 1977.  Modern Reservoir Engineering – A Simulation Approach. Crichlow, H.B.; PrenticeHall. 1977.  Basic Applied Reservoir Simulation. Ertekin, T.; Abou-Kassem, J.H.; King, J.R.; SPE Textbook Series N.3. 2001.


36

BASIC OVERVIEW BLOCK Module BOB 7A

SUBSURFACE PRODUCTION TECHNOLOGY Lecturer Mr. Ashutosh Shah joined Repsol in 2010, as a Head of Production Engineering at Dirección de Calidad de Operaciones (DCO), Madrid. He holds a Chemical Engineering Degree from the Indian Institute of Technology, Roorkee, India. He has worked with British Gas, UK, Enron International, USA and ONGC, India before joining Repsol. His last assignment was with BG Group, Reading UK as sub-surface development Manager. Objectives 1. Introduction to Production Technology. 1.1. Define the content and scope of Production Technology. 1.2. Relate the production system and the well performance to the long term reservoir

dynamics. 1.3. Discuss the integrated nature of production technology and its various technology

subsets. 1.4. Understand the impact of production technology on the economics of capital

investment planning and operating cost budgeting. 1.5. Discuss and define the concepts of well inflow performance and lift performance. 1.6. Explain the interaction, in terms of well life cycle economics, between capital

investment and operating expenditure.

2. Well Completion Design. 2.1. Evaluate and recommend bottom hole completion options based on well integrity and

reservoir management requirements. 2.2. Assess and recommend well designs for both production and injection wells. 2.3. Identify, evaluate and recommend functional capability of completion strings for a

variety of situations. 2.4. Describe the purpose and generic operating principles of major completion string

components. 2.5. Identify well design limitations and potential operational problems. 2.6. Assess well safety requirements and capabilities.

3. Perforating. 3.1. Describe the options, their advantages and disadvantages for perforating oil and gas

wells. 3.2. Describe how to select between over-balanced and under-balanced perforating. 3.3. Understand the importance of perforating charge design and what factors influence its

performance. 3.4. Discuss the importance of protecting the perforations against formation damage during

completion and workover operations.

4. Well Outflow and Total System Performance. 4.1. 4.2. 4.3. 4.4. 4.5. 4.6. 4.7. 4.8. 4.9.

Explain the concept of systems analysis. List four segments in the production system where pressure losses occur. Define inflow performance curve, outflow performance curve and the solution node. Explain how systems analysis is used to estimate production rates. List the three components of pressure loss for fluid flow in pipes. Describe the fundamentals of Multiphase Flow. Estimate pressure drop in tubing using graphical techniques. Identify the purpose of a choke. Define critical and subcritical flow.


37

5. Artificial Lift Review. 5.1. Explain the importance of Artificial Lift (AL) for world oil production. 5.2. List the different types of AL and explain their operating principle. 5.3. Discuss AL selection criteria.

6. Formation Damage. 6.1. Understand the importance of the near wellbore area in terms of formation damage

and poor well performance. 6.2. Calculate the cost of formation damage. 6.3. Identify the major sources of formation damage e.g. during drilling and completion

formation, production etc. as well as the appropriate remedial actions. 6.4. Provide guidelines for minimising formation damage during workover operations. 6.5. Indicate how the presence of formation damage can be identified in a production or

injection well.

7. Acidizing and other Matrix Stimulation Techniques. 7.1. Describe the role of and mechanism by which matrix stimulation improves well 7.2. 7.3. 7.4. 7.5.

production performance. Describe the well stimulation design methodology. Identify well stimulation candidates. Discuss the importance of the stimulation cycle. Prepare a treatment design i.e. select the acid formulation, acid volume and acid pump rate.

8. Subsurface and Surface Operations. 8.1. Discuss the properties of Oil and emulsions. 8.2. Describe operational problems associated with Water Production. 8.3. Describe the pipeline pigging operations.

Syllabus 1. Well Completions. 1.1. Types of Well Completion. 1.2. Basic Well Completion Component Names and their Functions. 1.3. Example Well Completions.

2. Perforating. 2.1. 2.2. 2.3. 2.4. 2.5. 2.6.

Shaped charge design and performance. Perforation Pattern and Well Inflow Performance. Perforation Charge Performance. Perforation Gun Types. Perforating Techniques. Impact on Well Productivity.

3. Well Performance. 3.1. Introduction. 3.2. Systems Analysis Of The Production System. 3.3. Importance of Hydrocarbon Phase Behaviour. 3.4. Reservoir Inflow Performance Review. 3.5. Tubing (Outflow) Performance. 3.6. “Gradient” or Pressure Traverse Curves. 3.7. Flow Maps and Correlations. 3.8. Temperature Modelling. 3.9. Surface Pressure Losses. 3.10. Completions Inflow Performance. 3.11. Computerized Well Performance Prediction Programs.


38

4. Introduction to Artificial Lift. 4.1. 4.2. 4.3. 4.4.

The need for Artificial Lift. Types of Artificial Lift. Selection of Artificial Lift. Integration of Artificial Lift in Field Development.

5. Formation Damage. 5.1. The concept of Skin. 5.2. The many Sources of Formation Damage Skin.

a) Drilling & Completion Operations. b) Production Operations and Reservoir Depletion. c) Workover Operations. 5.3. Workover Techniques to Minimize Formation Damage. 5.4. Recognition of the Presence of Formation Damage.

6. Acidizing & other Matrix Stimulation Techniques. 6.1. 6.2. 6.3. 6.4. 6.5.

Well Inflow and its improvement by Well Stimulation. An Introduction To Well Stimulation Economics. Candidate Selection. Matrix Stimulation Fluid Section. Matrix Stimulation Treatment Design:

a) Selection of Acid Composition. b) Selection of Treatment Volume. c) Selection of Injection Rate. d) Selection of Additives. e) Selection of Treatment Type. f) Selection of Diversion Technique. 6.6. Matrix Stimulation Field Campaigns.

7. Surface & Subsurface Operations. 7.1. 7.2. 7.3. 7.4. 7.5.

Emulsions. Scale Formation. Produced Water Management. Hydrates Formation. Pigging.

Textbooks and Consulting Books  “Production Operations” Vol. 1 and 2 (4th Edition). T. Allan and A. Roberts. Oil and Gas Consultants International, Tulsa, USA. ISBN: 0-930972-19-8.  “Petroleum Production Systems”. M. Economides, A. Hill and C. Ehlig Economides. Prentice Hall, 1994. ISBN: 0-13-658-683-X.  “Well Performance” (2nd Edition). M. Golan and C. Whitson. Tapir, Norway. ISBN: 0-13-946609-6.  “Surface Production Operations” Vol. 1 and 2. K. Arnold and M. Stewart. Gulf Publishing. ISBN: 0-87201-173-9.  “Production Optimization Using Nodal Analysis”. H. Beggs. Oil and Gas Consultants International. ISBN: 0-930972-14-7.  “Hydrocarbon Exploration and Production”. F. Jahn, M. Cook and M. Graham. Elsevier, No 46, Development in Petroleum Science. ISBN: 0-444-82883-4.


39

BASIC OVERVIEW BLOCK Module BOB 7B

SURFACE PRODUCTION TECHNOLOGY Lecturers Mr. Jose Enrique Gomis has over twenty one years’ experience as a process engineer. MSc Oil Refining, Gas, and Petro chemistry (UNIMET, 1994). BEICIP-FRANLAB (IFP subsidiary) Diploma, Postgraduate Cycle in Oil Refining, Gas and Petro chemistry. Mechanical Engineering (USB, 1990). Repsol YPF: Head of Production & Facilities UNAR. Head Production & Facilities EAA. Engineering Manager Gassi Touil Project. Senior Process Engineer, Technical Staff Group. Nous Group: Senior Process Consultant. Process Design Instructor to graduate students. PDVSA: Project portfolio coordinator. Project Leader. Senior Process Engineer. Surface facilities and gas engineering instructor. Responsible for Process Support and Operation Follow up, heavy oil and tar sands handling, dehydration and fractionation. UCV Instructor: Gas engineering undergraduate course instructor, Petroleum Engineering School.

Mr. Napoleon Villalba has over twenty eight years’ experience in the Oil and Gas industry, upstream and downstream, onshore and offshore, with experience throughout field Operations and Maintenance Management, Engineering, Construction, Facilities Commissioning, Projects Management, Field development conceptualizations, and Gas contracts negotiations and commercialization. Graduated as Process Control Systems Engineer in Los Andes University in Venezuela and post graduate diploma in Gas Business Development and Management programs. He has primarily worked for PDVSA, engineering consulting companies and Repsol, which joined early 2006. He is currently assigned to the new projects and field development revisions within the Direccion Ejecutiva de Desarrollo Tecnologico.

Objective 1. Provide a general overview of crude oil/ gas processing, the elements and equipment in an integrated surface facility plant and the impact in field development. 2. Understand the technical factors for the design and operation of a surface facility: fluid characteristics, quantities, specifications, location, data quality, etc 3. Review the fluid behaviour aspects relevant for the design and operation of a surface facility 4. Provide a general understanding of process operations: separation, dehydration, gas treatment, gas processing, water treatment, fluid transportation, etc. 5. Provide a basic understanding on how process equipment work and how they are designed and rated. 6. Discuss main elements related to managing a surface facility project: methodology, cost, schedule, etc.


40

Syllabus 1. Introduction: Basic unit of measurement. The Wellhead. The gathering network. The processing plant. Product specifications. Production handling basic concept and schemes. The transport system. Impact on field development. Project metrics and cost. Environment: Onshore. Offshore. Technologies 2. Hydrocarbon fluid behaviour: 2.1. Hydrocarbon composition: Chemical components. Contaminants. PONA. Oil cuts. 2.2. Natural gas properties: Composition. Specifications. Density and Specific Gravity.

Compressibility. Viscosity. Heating value. Liquid content. 2.3. Liquid hydrocarbon properties: Density and specific gravity. Characterization factor.

Assays. TBP. Critical properties. Pseudo components. 2.4. Phase behavior: Pure component. Mixtures. Fluid phase diagrams. Reservoir

applications. Separator applications. Fluid transport applications. 2.5. Equation of state: Ideal gas. Real gas. Cubic EOS´s. Virial EOS´s. 2.6. Phase equilibrium: Concepts. Ideal equilibrium constant. Simplified methods. EOS

methods. Phase calculation. Dew point. Bubble point. 2.7. Gas-Water Behavior: Water content in natural gas. Correlations. Hydrates. Hydrate inhibition. Corrosion. Corrosion calculations.

3. Separation and oil treatment 3.1. Liquid stabilization: Vapor pressure. Process schemes. Separation stages. Selection

criteria. 3.2. Separators: Production separators. Test separators. Scrubbers. Slug catchers. Filters. KO

drums. 3.3. Process vessels: Operating principle. Process design and sizing. Mechanical design. 3.4. Crude Oil dehydration: Operating principle. Sizing considerations. The bottle test. Gun

barrels. FWKO´s. electrostatic equipment. Desalters. 3.5. Distillation & Fractionation: operating principle. Fractionation. Sizing. Internals.

Operational features.

4. Water Treatment 4.1. 4.2. 4.3. 4.4.

Water Specifications. Basic Principles and equations. Process Schemes. Process equipment.

5. Natural gas treatment and processing 5.1. Natural gas treatment: general aspects. Gas dehydration. Glycol process. Adsorption

processes. Acid gas problems. Gas sweetening. Amine processes. Physical solvent process. Solid bed process. Membranes. Mercury. 5.2. Natural gas processing: Dew pointing. NGL extraction. LPG extraction. Process schemes. Oil Absorption. Mechanical refrigeration. J-T expansion. Turbo expansion. NGL/LPG storage.

6. Oil & Gas transportation 6.1. Fluid flow: Terms & definitions. Basic concepts. Single phase. Multiphase flow. Piping

process sizing. Mechanical sizing. 6.2. Liquid pumping: General concepts. Centrifugal pumps. Rotary pumps. Reciprocating

pumps. Drivers. 6.3. Gas compression: Thermodynamic of compressors. The process. Reciprocating

compressors. Centrifugal compressors. Screw compressors. Drivers.

7. Thermal equipments 7.1. Heat transfer: Definitions. Heat transfer mechanism. Basic equations. Heat transfer

resistances. The driving force... Sizing and rating. Shell & tube heat exchangers. Hairpin heat exchangers. Hairpin heat exchangers. Air coolers.

7.2. Heat exchangers:


41

7.3. Heaters and Furnaces: Definitions. Combustion. Heater design. Operational features.

8. Measurement and controls 8.1. Flow measurement: General concepts. Measurement classification. Custody transfer.

Production allocation. Process control. Measurement types. Orifices. Turbines. Coriolis based. Ultrasonic. 8.2. Process control: flow control. Level control. Temperature control. Pressure control. Control valves.

9. Safety 9.1. Design

considerations: Design pressure. Design temperature. Depressurization systems. Blow down systems. 9.2. Equipments: Safety valves. Sizing. 9.3. Systems: Disposal systems. Open systems. Close systems.

Contingencies.

10. Project Management 10.1. Project Stages. 10.2. Integrated Project Management (GIP Guidelines). Visualization. Conceptualization.

Definition. Execution. 10.3. Front End Loading. 10.4. Cost Estimation. Risk. Contingencies. Accuracy. Allowances. Contract types.

Main Exercises and Tutorials. Students are required to have handheld calculator and Excel Textbook will be handed over by downloading the electronic copy in each student computer using the Repsol e-library catalogue. Basis of Design, Block diagrams, Process Flow diagrams and equipment lists will be handed out to the students covering a real case of a plant design for collecting the gas and condensate, separate the fluids, dew point the gas, stabilize the liquids, remove the CO2, compress the gas, pump the liquids, transport both fluids, and extract LPG will be studied. During the course, some of these exercises will be developed: gas properties and pseudo critical properties, gas compressibility factor, bubble point and dew point of multi component mixture, water content on natural gas, separator design, piping design, pipeline and pumping system, gas compressor power estimation. Program Day 1  Introduction.  Hydrocarbon phase behaviour.  Exercises. Day 2  Separation & oil treatment.  Exercise.  Water Treatment. Day 3  Natural gas treatment & processing.  Oil Transportation.  Exercises. CENTRO SUPERIOR DE FORMACION REPSOL

42

Day 4     

Gas compression. Thermal equipments. Measurement and controls. Safety. Exercises.

Day 5  Utilities.  Project Management.  Course Examination. Software Applications    

Open Process design software in Basic 3.2 to be handed out during the course. Excel spreadsheets. Hysys (see Team Project 3rd term). Questor Offshore (see Team Project 3rd term).

Textbooks and Consulting Books  “Surface Production Operations Volume I and II from K. Arnolds and M. Stewart”. Second Edition  “Gas Conditioning & Processing Volume I, II, III”. JMC Campbell. Campbell Petroleum Series, Norman, Oklahoma. Library of Congress Catalogue Card 76-15.  “PVT and Phase Behaviour of Petroleum Reservoir Fluids”. Danesh, Ali. Elsevier. ISBN: 044482196 1.  “A Working Guide to Process Equipments”. Lieberman N, Lieberman, E. Mc Graw Hill. ISBN 0-07-038075-9.  “Oil Field Processing Volume One: Natural Gas & Volume Two: Crude Oil”. Manning F & Thompson R. PennWell Books, Tulsa Oklahoma. ISBN 0-87814-342.


43


ECONOMIC EVALUATION Lecturer Mr. Gerardo Gonzalez is Manager of the Economic Evaluation Control and Studies Department, in Repsol Upstream Planning & Resources. He received a BSc degree in Economics from “Universidad Autonoma de Madrid” and a Technical Mining Engineering degree from “Universidad de Oviedo”. He worked for more than eight years as an Offshore Drilling Engineer in Hispanoil and Eniepsa Spanish operations. In 1988 he started to work as a Senior Economist in Repsol Exploracion New Ventures, responsible in the elaboration of economic models for E&P investment analysis. From 1990 to 1999 he served as Senior Economist in Repsol Exploracion Planning. Then, from 1999 to 2002, he was a Senior Economist in Repsol S.A. Planning (Gas & Power). He has taught courses for NIOC technical staff in Teheran (Iran) and has published papers related to Oil & Gas industry in Mexico and Spain. Objectives 1. 2. 3. 4. 5. 6. 7.

Understand the main targets of the E&P companies. Become acquainted with the main management indicators in a E&P company. Be acquainted with E&P contract features. Learn how to perform an economic evaluation of an E&P project. Get to know and understand the fundamentals of decision analysis. Become acquainted with the E&P accounting standards. Understand Oil & Gas markets. Their structures, characteristics and price mechanisms.

Syllabus 1. Main targets of E&P companies. 1.1. E&P cornerstone idea. 1.2. Technical risk in the E&P asset lifecycle. Exploration, appraisal, development, production 1.3. 1.4. 1.5. 1.6.

and abandonment. Ways of land acquisition. Up-front payments. Farm in-out economic consequences. Areal extent. “Ground floor”. Working obligations. Mandatory and discretionary programs. Operating environment impacts on economic viability.

a) Factors to be considered in cost estimation. b) How technological advances press costs down. c) Costs for recent developments. 2. What’s the E&P industry doing. 2.1. 2.2. 2.3. 2.4. 2.5. 2.6. 2.7. 2.8. 2.9.

E&P main indicators. Investor benchmarking. Reserve replacement. Ways to replace reserves. Reserve life. Finding cost. Full cycle cost. Trends. Exploration performance. Write-off rate. Trends. Reinvestment ratio. Trends. E&P expenditures per production unit. Trends. E&P current cost escalation. E&P is still the most important business in oil-gas industry. E&P profitability by geographic area.


44

3. E&P Contract types. Historic evolution. 3.1. Concession. Tax-royalty system. Royalty “in-kind” and “in-cash”. 3.2. Production sharing contracts.

a) Cost-oil. Profit-oil. Excess cost-oil. Cost-oil limit. “PSC effects”. b) Net reserves. 3.3. 3.4. 3.5. 3.6.

Service contract. With or without risk. Association contract. New contracts: "k factor" (Algeria), “Buy-back” (Iran). Other contract issues.

a) Work program. Relinquishment. Sole risk. Force Major. b) Carried National oil Company. c) Commercial discovery. d) Depreciation schedule. Carry forward clause. e) Associated fiscal terms: bonus, “ring-fence”, “price cap”, “uplift” and “domestic obligation”. f) Government-Contractor takes. Differences among contracts and among countries. 4. Economic evaluation. Objectives of an economic evaluation. “Economics” in the E&P asset lifecycle: purpose, key variables, and risks. Phases of a project's economics. Evaluation network. Measures of profitability. Characteristics. Economic evaluation. Full cycle and half cycle. Discounted net cash flow method. Building the cash flow. Measures of profitability more commonly used: payback period, maximum financial exposure, profit to investment ratio, internal rate of return, net present value, discounted profit to investment ratio, etc. Characteristics. Pros and cons. 4.8. The discount rate. Factors to be considered. 4.9. Answering “what if” questions. Sensitivity analysis. Looking for the key uncertainties. 4.10. Sustainable development in the energy sector. 4.1. 4.2. 4.3. 4.4. 4.5. 4.6. 4.7.

5. Decision analysis. 5.1. 5.2. 5.3. 5.4. 5.5. 5.6. 5.7. 5.8.

Concepts: uncertainty, exposure to uncertainty, risk, etc. Basics of probability and statistics concepts. The “shape” of oil patches uncertainty. Expected value concept. Meaning and interpretation. Decision trees. Chance node. Decision node. Solving a decision tree. Maximum tolerable dry hole risk. Preference theory concepts.

6. Accounting and Financial Statements. 6.1. 6.2. 6.3. 6.4. 6.5. 6.6.

“SFAS 69”. SEC Standards for booking reserves. “Ceiling test” and Year Closing. Booking reserves. Full Cost and Successful Effort methods. The unit-of-production depreciation method. Final summary.

7. Miscellaneous. 7.1. 7.2. 7.3. 7.4. 7.5.

Oil market. Prices. Why are prices so difficult to forecast? Gas Market has a regional structure. Prices. Oil vs. Natural Gas. Different risks. Gas market. Net-back and build-up prices. Examples. Final summary.


45

Main Exercises and Tutorials Tutorial: Performance of an economic evaluation based on the contractual terms of a foreign country.       

Country overview. Country oil-gas sector. Government hydrocarbon policy. Contractual terms. Use of an economic model. Technical inputs of the project: capex, opex and production profiles. Oil-gas price references. Historic and futures series. Dollar and Euro interest rate references.

Program This course lasts 5 days. Day 1:      

Introduction. Resources and reserves. Why economics? The value chain. Business integration. Companies convergence. The impact of the financial and economic crisis on global energy investment. The end of oil age? E&P industry. The cornerstone idea. Geological, Commercial and Economical Success. “Acreage” acquisition: Negotiations, Farming-out, international tenders. Economic consequences.  Industry indicators: Finding, Finding $ Development, Full cycle Costs. Reserve replacement, reinvestment ratio, reserve life and write-off rate.  Why contracts? Economic rent. Objectives of E&P actors.  Day’s summary. Day 2:  Fiscal systems: Concession, PSC, Service and Association contracts. Buy back and others  Sliding scale, price cup, investment uplift, depletion allowance, overriding royalty.  Taxes in lieu. PSC effect. Royalty in kind, Net reserves. Other contract issues. The Laffer curve.  General objectives of fiscal regimes.  E&P Economics. How to value a project? Measures of profitability. Characteristics. Weakness.  Cash Flow. Economic Limit.  Day’s summary. Day 3:  Pay Out, ROI, Time-value of money. Compounding and discounting, IRR, to lend or to borrow? Mutually exclusive projects. NPV, pros and cons. Multiple equation solutions.  Inflation, interest rate and discount factor. End-period and mid-period discounting.


46

 What if clauses? Scenarios analysis.  Accounts and financial statements. Cost-based models. Balance sheet, Profit & Loss. ROE, ROCE.  GAAP. Why depreciation? Property loose value. Unit-of-production amortization method.  Ceiling Test.  Tax planning.  Day’s summary. Day 4:       

Decision Analysis. Basic statistics. Expected Value. Decision Tress. Booking reserves. Oil and gas prices and markets. Oil prices and costs. Day’s summary. Economic evaluation and economic model presentation . Exam. Perform an economic evaluation.

Day 5:  Exam. Perform an economic evaluation. Software Applications  Microsoft Office. Textbooks and Consulting Books  “Decision Analysis for Petroleum Exploration”. Paul D. Newendorp. PennWell Books, 1975.  “International Petroleum Exploration Economics”. N.W. Miller. IHRDC, 1998.  “International Petroleum Fiscal Systems and Production Sharing Contracts”. Daniel Johnston, 1994.  “Dealing with Risk and Uncertainty in Exploration”. Peter R. Rose. The American Association of Petroleum Geologists, 1987.  “Decisiones Optimas de Inversion y Financiacion en la Empresa”. Andres Suarez. Piramide. 1984.


47


RISK ANALYSIS Lecturer Mr. Antonio Suarez has more than 30 years’ experience working on the E&P industry. He graduated as Mining Engineer in ETSIMO, Spain, and he also has a M.Sc. in Geophysics by Stanford University, and a M.Sc. Finances by the London Business School. He has worked mainly for Chevron Overseas and Repsol, initially as well site geologist, then seismic interpreter and explorationist, and later becoming Director New Ventures and M.D. Business Development for Repsol. With great concern for education, Mr. Suarez has been always in touch with Universities and Students, and he is attending Energy Meetings and giving talks on International E&P Conferences. This module is aimed to understand and learn how to cope with risks and uncertainties related to E&P activities Objectives: 1. 2. 3. 4. 5. 6. 7.

Identify risks and uncertainties intrinsic to the Exploration and Production. Understand the basic statistical measures and probability distributions. Be able to assign Exploration Prospect Risk. Learn how to estimate Prospect/Field probability distribution of sizes. Learn how to deal with risk and construct decision trees analysis. Understand methods for risk diversification and Portfolio Management. Understand the New Ventures process, competitive tenders and bidding rounds.

Syllabus 1. Introduction to the Risks associated to the Business of Exploration and Production of Hydrocarbons. 1.1. The Oil and Gas Business. The E&P process and concept of volatility on results. 1.2. Definition of Risk and Uncertainties. 1.3. The concept of Expected Value.

2. Basic Statistics Applied to the Exploration and Production. 2.1. 2.2. 2.3. 2.4.

Sorting data. Creating frequency distributions Discrete or continuous distribution of values Measures of central tendency. Normal distributions and Lognormal distributions.

3. Dealing with Risk. Improving Estimates. Defining Exploration Risk. 3.1. 3.2. 3.3. 3.4.

Discriminating Facts from Opinions. Subjective Probability. How to improve estimates. The value of data and knowledge. Defining Geological/Technical Risk Variables. Quantifying Prospect Risk.

4. Basic Principles of Prospect Resources/Reserves Calculation. Uncertainty on size. 4.1. Review of Basic variables to calculate volume of hydrocarbons in situ. 4.2. Deterministic versus Probabilistic approaches to size calculation. 4.3. Different Probabilistic Methods used on E&P to cover for uncertainty on size.

5. Basic Prospect and Exploration Block valuation. 5.1. Combining Prospect Risk with Size uncertainty.


48

5.2. Prospect Valuation. Decision tree analysis. Technical or economical success. 5.3. Multiple Prospects, Exploration Block valuation.

6. Risk Diversification. Portfolio Management. 6.1. Exploration Portfolio. Leads and Prospects. 6.2. Portfolio valuation, risk distribution and Prospect Ranking. 6.3. The concept of Expected Exploration Resources. From Resources to Reserves.

7. The New Ventures Process. 7.1. Acquiring new assets. How to assign value. 7.2. Competitive Tenders and Bidding Rounds.

Program Day 1    

Risks Associated to the E&P. Basic Statistics. Dealing with Risk Exercises 1, 2 & 3.

Day 2  Prospect Resources Calculation.  Prospect & Block Valuation.  Exercises 4 & 5. Day 3    

Portfolio Management. New Ventures. Exercise 6. Course Examination.

Main Exercises and Tutorials      

Exercise 1: Estimating Expected Value. Gambling exercise. Exercise 2: Making estimations. Uncertainty Game. Exercise 3: Mapping Exercise. Alternative options & value of knowledge. Exercise 4: Assigning Prospect Risk. Exercise 5: Probabilistic Distribution of Prospect Size. Exercise 6: Exploration Bidding Round. A Competitive Tender Simulation.

Software Applications  Microsoft Office. Textbooks and Consulting Books  Megill, R. E. (1984). An Introduction to Risk Analysis, 2nd Edition. PennWell Publishing Co. Tulsa.  Megill, R. E. (1992), Estimating prospect sizes, Chapter 6 in: R. Steinmetz, ed., The Business of Petroleum Exploration: AAPG Treatise of Petroleum Geology, Handbook of Petroleum Geology, pp. 63-69.


49

 Newendorp, P. (1975), Decision Analysis for Petroleum Exploration. PennWell Publishing Co. Tulsa.  Murtha, J. (2001), A guide to Risk Analysis. Supplement to Hart’s E&P  Otis, R.M. & Schneidermann, N. (1997) Process for Evaluating Exploration Prospects. AAPG Bulletin, V. 81, No. 7  Riis, T. (1999), Quantifying the Value of Information, Petroleum Engineer International, June 1999, pp.48-50.  Rose, P. R., (1987), Dealing with risk and uncertainty in exploration: how can we improve?, AAPG Bulletin, vol. 71, no. 1, pp. 1-16.  Schuyler, J. R. (1996), Decision Analysis in Projects. Project Management Institute, Sylva, North Carolina, 144 pp.  White, D. A. (1993), Geologic risking guide for prospects and plays, AAPG Bulletin, vol. 77, no. 12, pp. 2048-2061.


50


OFFSHORE STRUCTURES Lecturer Dr. Manuel Moreu is Professor of Offshore projects at the Spanish School of Naval Architecture. He is a Naval Architect and holds a PhD in Offshore from M.I.T. He has participated in all kind of projects, fixed and floating, drilling, production and storage etc. His experience has been gained working for the Oil Companies, and for the main Engineering Contractors. Objectives 1. Introduction to the Offshore Installations. 1.1. 1.2. 1.3. 1.4.

The transition from shore. The environmental conditions. The seakeeping. The station keeping.

2. The fixed production units. 2.1. Jackets. 2.2. Gravity Platforms. 2.3. Jack-ups.

3. Mobile Offshore Drilling Units. 3.1. 3.2. 3.3. 3.4. 3.5.

Floating drilling. Submersible. Jack-up. Semisubmersible. Drillship and barges.

4. Floating Production. 4.1. 4.2. 4.3. 4.4.

Well testing and early production. Semisubs. F.P.S.O. Spar and other deep draft solution.

5. The Hybrid solution. 5.1. The TLP.

6. The subsea production. 6.1. The subsea wellheads. 6.2. The templates. 6.3. The flowlines.

7. Export. 7.1. The storage. 7.2. The pipeline.

8. Support fleet. 8.1. 8.2. 8.3. 8.4.

Exploration. Installation. Operation. Abandoning.

9. Planning and costing. 9.1. Production units.


51

Syllabus 1. The start of the offshore. 1.1. Origin of offshore development. 1.2. Environmental conditions. 1.3. Water depth.

2. The Jacket. 2.1. 2.2. 2.3. 2.4. 2.5.

Considerations for Design. Jacket, piling, MSF and topsides. The installation. Drilling. Production.

3. MODU - Mobile Offshore Drilling Units. 3.1. 3.2. 3.3. 3.4. 3.5.

Considerations for Design. The drilling riser. The motion compensation. The mooring system. The D. P.

4. Subsea wellheads. 5. Floating production. 5.1. From a MOU. 5.2. From a FPSO. The storage. 5.3. The production risers.

6. Export. 6.1. Shuttle. 6.2. Single point mooring. 6.3. Pipeline.

Textbooks and Consulting Books      

IMO MODU CODE. Harris Deepwater Floating Drilling Operations. Petroleum Publishing Company. ETA Offshore Seminars. Developments in offshore engineering. GPC Herbich.


52


TIMETABLE September-December 2014


53

Week 2 Week 7 Week 11 Week 12 Week 15 Week 16

DECEMBER

Week 14

Week 13

NOVEMBER

Week 10

Week 9

Week 8

OCTUBRE

Week 6

Week 5

Week 4

SEPTEMBER

Week 2

Week 1

Group A 1 2 3 4 5 8 9 10 11 12 15 16 17 18 19 22 23 24 25 26 29 30 1 2 3 6 7 8 9 10 13 14 15 16 17 20 21 22 23 24 27 28 29 30 31 3 4 5 6 7 10 11 12 13 14 17 18 19 20 21 24 25 26 27 28 1 2 3 4 5 8 9 10 11 12 15 16 17 18 19

Group B

Hours A

Hours B

30

30

Introduction to Repsol Business Reps Refreshment courses (Afternoon) T.Zapata / F. Mustieles BOB 1C Structural Geology A. Chambers

BOB 1B Basin Analysis and Petroleum Systems A. Racero

37,5

37,5

BOB 1B Basin Analysis and Petroleum Systems S.Quesada

BOB 1C Structural Geology A. Chambers

37,5

37,5

37,5

37,5

BOB 4 Drilling Eng. J. Ford

BOB 5 Geophysics C. Lupascu

BOB 3 Well Logging S. Winstanley

37,5

37,5

BOB 3 Well Logging S. Winstanley

BOB 5 Geophysics C. Lupascu

37,5

37,5

BOB 2 Geology Field School Gessal

BOB 6A Reservoir Geology and Characterization J. Prieto Fanjul

37,5

37,5

BOB 6A Reservoir Geology and Characterization P. Corbett

BOB 6B Reservoir Engineering M. Prida

37,5

37,5

BOB 8 Economic Evaluation G. Gonzalez

BOB 6D Well Testing E. Izaguirre

30

37,5

BOB 6B Reservoir Engineering M. Prida

BOB 6E Reservoir Simulation F. Mustieles

37,5

37,5

BOB 2 Geology Field School Gessal

30

37,5

BOB 7A Sub-Surface Production Technology TBD

37,5

37,5

37,5

30

37,5

37,5

30

30

37,5

37,5

570,0

577,5

BOB 9 Risk Analysis A. Suarez BOB 6D Well Testing E. Izaguirre

BOB 6E Reservoir Simulation F. Mustieles

BOB 10 Offshore Structures M. Moreu

BOB 7A Sub-Surface Production Technology Ashutosh Shah

BOB 7B Surface Production Technology J.E.Gomis

BOB 10 Offshore Structures M. Moreu

BOB 9 Risk Analysis A. Suarez

BOB 7B Surface Production Technology N.Villalba

BOB 8 Economic Evaluation G. Gonzalez

Total Lecture Hours


54


BLOCK II: SPECIALIZATION BLOCK January to March 2015 Heriot-Watt University, Edinburgh  Petroleum Engineering  Reservoir Evaluation and Management  Petroleum Geosciences


55

General information about the School The Institute of Petroleum Engineering is a specialised centre in teaching, training and research with the largest PE research program in the UK. The Institute is multi-disciplinary and focuses on upstream oil and gas resources. It was founded in 1975 to work with the emerging upstream North Sea industry and now has well established industrial and academic links around the world. The Institute currently has 100+ staff, 50 research students and 80+ residential master’s students. There are also overseas and Distance Learning teaching initiatives involving more than 300 students worldwide. After the completion of the Basic Overview Block in Madrid, the E&P Master’s students will face the opportunity of living in a well organised university campus (Riccarton) plenty of student facilities and natural environments:        

Residential Hall. Dining Hall. Library. Computing rooms. Student Union. Centre for Sports and Exercises. Healthcare. Chaplaincy.

There are four specialization programs:  PE: Petroleum Engineering  REM: Reservoir Evaluation and Management  PetGeo: Petroleum Geosciences Depending on the background and performance during the first block, each student is allocated to one of these programs. This specialization block covers all the modules from January to March. After the lectures, the students will go back to Madrid and take the Heriot-Watt examinations at CSFR. Registration in HWU will take place in Riccarton Campus on January 5th, 2015. Lectures start on January 6th, 2015. Further information and links of interest: www.hw.ac.uk http://www.postgraduate.hw.ac.uk/pet/ http://www.hw.ac.uk/student-life/edinburgh.htm www.visitscotland.com http://www.edinburgh.org/


56

Petroleum Engineering (PE) The aim of the course is to extend the skills developed at undergraduate level and augment them with specialised courses relevant to Petroleum Engineers. The course was established in 1975 based on industry preferences. Entrants to the course will normally have a good honours degree in engineering or a relevant science discipline such as Geology, Physics, Chemistry or Mathematics. Reservoir Evaluation and Management (REM) The aim of the course is to extend the skills developed at undergraduate level and during work experience, and to augment them with specialised courses relevant to earth scientists and engineering graduates who wish to study the fundamentals of Petroleum Reservoir Geo-engineering. The course was established in 1993. It was developed from innovative research, within the Institute, that concentrates on integrating the geoscience and fluid flow characteristics of petroleum reservoirs. It therefore produces graduates who understand the effects of both reservoir structure and properties on the exploration for and production of hydrocarbon reservoirs. Entrants to the course will normally have a good honours degree in geology, geophysics, engineering or a relevant science discipline such as Geology, Physics, Chemistry or Mathematics. Petroleum Geosciences (PetGeo) This is a collaborative MSc between the University of Edinburgh School of Geosciences, Heriot-Watt Petroleum Engineering and Newcastle University Fossil Fuels. The objective of this MSc is to provide a thorough training in aspects of subsurface Geology, Geophysics and Geo-engineering, which relate to the Exploration, Appraisal and Development of subsurface resources (particularly hydrocarbons). Entrants to the course will normally have at least an upper second class honours degree or its equivalent in a Geological or Geophysical science. Depending on the career choice, a specialised module differs from common courses.


57


SPECIALIZATION: PETROLEUM ENGINEERING Heriot-Watt University Modules:  Production Technology  Reservoir Engineering II (Well Testing)  Reservoir Simulation  Petroleum Economics


58

SPECIALIZATION BLOCK: PE PRODUCTION TECHNOLOGIES

Module G11PT Tutor DR Davies. Objectives 1. 2. 3. 4.

Identify the major components of the production system. Consider the options available to efficiently complete a well. Understand and apply the theory behind Reservoir - Well - Facility flow modelling. Examine the techniques available to enhance production from both reservoir and well. 5. Design appropriate procedures to ensure optimal initial production. 6. Understand the process of delivering and treating reservoir and injection fluid at the surface. Syllabus 1. Introduction. 1.1. Role of production engineer. 1.2. Review of wellbore/reservoir connection and implications for fluid flow.

2. Well performance. 2.1. PI for oil and gas wells in steady state flow. 2.2. Concepts of flow in pipes and ipact of pressure loss components and horizontal pipes. 2.3. Physical property variation in flow up the wellbore for single phase gas and oil flow and

for multi-phase flow. 2.4. Slip and hold up and appreciate impact on flow efficiency and tubing sizing. 2.5. Gradient curves concepts. 2.6. Flowing bottomhole pressure based on assumed tubing head pressures and the intake

curve of flowing bottomhole pressure versus rate.

3. Well completions. 3.1. Evaluate bottom hole completion options. 3.2. Geometrical configurations for drilled wellbores for both production and injection

applications. 3.3. Generic operating principles for major completion equipment components. 3.4. Tubing for production/injection. 3.5. Wellheads. 3.6. Xmas trees. 3.7. Packers. 3.8. Seal assemblies. 3.9. Subsurface safety valves. 3.10. Nipple profiles. 3.11. Flow control and circulation devices. 3.12. Packer selection.

4. Perforating. 4.1. Options and advantages/disadvantages for perforating oil and gas wells. 4.2. Over balance and under balanced perforating. 4.3. Charge design and factors that influence performance.


59

4.4. Effect of completion and work over operations.

5. Advanced wells. 5.1. 5.2. 5.3. 5.4.

Development of advanced wells. Improvement in productivity. Advantages compared to traditional wells. Multilateral wells.

6. Artificial lift. Explain the importance of Artificial Lift (AL) for world oil production. Selection of AL based on ranking criteria. Electric submersible pump. Beam pump. Fluid driven hydraulic pumps (explain the mode of operation of the (i) Jet pump; (ii) Weir multiphase pump; (iii) Hydraulic pump. 6.6. Progressive cavity pump. 6.1. 6.2. 6.3. 6.4. 6.5.

7. Gas lift. 7.1. 7.2. 7.3. 7.4. 7.5. 7.6.

Describe the gas lift process. Identification of application areas/advantages for gas lift. Well unloading process. Gas lift hardware components. Gs lift completion design. Intermittent gas lift and plunger lift processes.

8. Formation damage. 8.1. 8.2. 8.3. 8.4. 8.5. 8.6. 8.7.

Formation damage and poor well performance. Major sources of formation damage. Appropiate remedial treatments. Production related formation damage. Scale, wax, asphaltene deposition. Scale inhibitors. Perforating damage.

9. Matrix acidizing. 9.1. 9.2. 9.3. 9.4. 9.5.

Types of matrix stimulation techniques. Primary chemical reactions in sandstone and carbonate acidizing. Acid selection. Additives. Acidizing treatment design.

10. Hydraulic fracturing. 10.1. Productivity Increase Factor (PIF) achievable by HF. 10.2. Role of Rock Mechanics in supplying basic design data for an HF treatment. 10.3. Fracture propagation pressure record analysis to derive basic design data. 10.4. Fracture propagation models. 10.5. Hydarulic fracture geometry (fracture shape and length). 10.6. Hydarulic fracture treatment design procedure. 10.7. Hydraulic fracturing treatment operation.

11. Sand control. 11.1. Decision to install sand control during the original completion design. 11.2. Definition of sand problem in the field. 11.3. Surface equipment/operations to cope with sand production. 11.4. Sand control options. 11.5. Liner/screen design. 11.6. Gravel pack design.


60

12. Field development concepts and fluid processing. 12.1. Design and operation of the production facilities. 12.2. Outline production process scheme. 12.3. Components and operation of a 3 phase separator. 12.4. Fiscal measurement of produced crude oil. 12.5. Pipeline “pigging” operation. 12.6. Gas handling facility - NGL separation and stabilization. 12.7. Gas dehydration and sweetening. 12.8. Chemical composition of formation water. 12.9. Operational problems (scale, corrosion, etc). 12.10. Oily water treatment. 12.11. Disposal options. 12.12. Source of injection water and surface preparation.

Assessment methods  Examination: 80%  Coursework: 20%


61

SPECIALIZATION BLOCK: PE Module G11WT

RESERVOIR ENGINEERING WELL TEST ANALYSIS Tutor S. Zheng. Objectives 1. Understand the diffusivity equation and the derivation of analytical solutions related to reservoir features (wells, fractures, aquifers). 2. Use the analytical solutions to describe fluid flow in a reservoir. 3. Calculate reservoir permeability in simple and complex reservoir geometries. Syllabus 1. Introduction to well testing. 1.1. 1.2. 1.3. 1.4. 1.5. 1.6. 1.7.

Reservoir depletion and the application of reservoir limit testing. Generalized form of the radial inflow equation. Dietz shape factors. Reservoir damage or improvement and skin factor. Brons and marting pseudo-skin. Arithmetic average in calculating equivalent permeabilities for layered systems. Effects of perforations on well production.

2. Pressure transient analysis. Objectives of exploration well testing. Derivation of diffusivity equation for radial inflow. Dimensionless versions of the linear de. Linearized radial flow equation for the line source boundary condition. Logarithmic approximation to the exponential integral solution of the line source. Solution. 2.6. Principle of superposition and its application to the specific case of build-up testing i.e. The horner time function. 2.7. Construction of semi-log plots for basic ideal data sets and solve for basic reservoir parameters. Kh, skin. 2.1. 2.2. 2.3. 2.4. 2.5.

3. Late time boundary and depletion effects. 3.1. 3.2. 3.3. 3.4. 3.5. 3.6. 3.7. 3.8.

Geological features which present themselves as no-flow boundaries. Importance of fault detection by pressure analysis. Method of images and state the solution to the diffusivity equation for the system. Relationship between the logarithmic approximation and the semilog plot for MTR and LTR. Distance to boundaries. Identify the five basic elementary fault models log-log diagnostic plot and be able to use derivative type curves. Relationship between the ratio of the slopes of the MTR and LTR on the semilog plot and the angle of intersection of faults. Identification parallel faults.

4. Distributed pressure measurements. 4.1. 4.2. 4.3. 4.4.

RFT tool. Analysis of a pretest record. Supercharging and supercharging index. RFT data presentation.


62

4.5. Benefit of the new generation MDT device.

5. Exploration applications of distributed pressure measurements 5.1. 5.2. 5.3. 5.4. 5.5. 5.6. 5.7. 5.8.

Nature of an unproduced reservoir at gravity-capillary equilibrium. RFT gradient intersection coincide with the free water level. Paleo-contacts and the concept of residual oil. RFT indication of water gradient in a trapped oil zone. Detection of tar mats. Effect of oil wet rock on a RFT survey. Geological significance of a perched contact and its recognition on a RFT survey. Tilted contacts and dynamic aquifer effects.

6. Field development applications of distributed pressure measurements Problem of discrimination of supercharged points. Effect of vertical component of flow on the pressure gradient. Theory of single phase flow Interpretation of gradients in simple multiphase flow situations. Vertical pressure equilibrium. Partially communicating faults and inter-block Pls. Relation between fault multipliers in a simulator and intrinsic fault transmissibility indices. 6.8. Use of compartmentalized material balance for RFT interpretation. 6.9. Importance of production logging data as a complement to RFT data. 6.1. 6.2. 6.3. 6.4. 6.5. 6.6. 6.7.

7. Reservoir management 7.1. 7.2. 7.3. 7.4. 7.5.

Production logging surveys. Integration of well test and core analysis studies with PLT surveys. Importance of the reservoir monitoring. Understand the selective inflow performance (SIP) technique. Sign of infill drilling of injection wells.



63

SPECIALIZATION BLOCK: PE Module G11RS

RESERVOIR SIMULATION Tutor K Sorbie, E. Mackay, G. Pickup. Objectives 1. Develop an understanding of the role of simulation in reservoir engineering. 2. To gain insight into the value of simulation. 3. To provide the appropiate numerical techniques to enhance hydrocarbon recovery. Syllabus 1. Introduction. 1.1. Description of a simulation model. 1.2. Simplifications and issues that arise in going from the description of a real reservoir to a

reservoir simulation model. 1.3. Description or reason and circumstances simple or complex reservoir models are

required to model reservoir processes. 1.4. Input data is required. 1.5. Typical outputs of reservoir simulations and their use in reservoir development.

2. Basic concepts in reservoir engineering. Material balance equation for an usaturated oil reservoir. Conditions under which the material balance equations are valid. Single and two-phase darcy law in one dimension (1d). Gradient and divergence operators as they apply to the generalized (2d and 3d) darcy law. 2.5. Permeability as a tensor quantity. 2.6. 2d and 3d darcy law with permeability as a full tensor. 2.1. 2.2. 2.3. 2.4.

3. Reservoir simulation model set-up. 3.1. Simulation input - issues to be addressed by simulation, input data required, format of

data. 3.2. Simulation output - output of calculations, quality check output data to check for error

in input, post-processing analysis. 3.3. Analysis of results - identify impact of reservoir engineering principles in calculation

performed, identifiy numerical effects and impact of grid block size and orientation on result, perform simple upscaling calculation to address numerical difussion.

4. Gridding and well modelling 4.1. 4.2. 4.3. 4.4. 4.5. 4.6. 4.7. 4.8. 4.9.

Concept of gridding and of spatial and temporal discretisation. Types of grid in 1D, 2D and 3D used in reservoir simulation. Numerical dispersion and grid orientation and the solution to these numerical problems. Local grid refinement (lgr), distorted, pebi and corner point grids. Grid fineness/coarseness. Streamline simulation. Well models and productivity index (PI). Average grid block pressure and peaceman formula. Concept of multi-phase flow to calculate PIw and PIo.

5. Flow equations. 5.1. Physics of single phase compressible flow through porous media. 5.2. Equation for single phase compressible flow (PDE).


64

5.3. Linearization of pde for slightly compressible flow involving the hydraulic diffusivity. 5.4. Extension of the single phase pressure equation to 2d. 5.5. Conservation + darcy’s law in the two phase case to arrive at the two phase flow

equations for compressible fluids and rock.

6. Numerical methods in reservoir simulation. 6.1. Simple finite difference expressions for derivatives, (∂p/∂x), (∂p/∂t) and (∂2p/∂x2). 6.2. Forward difference, the backward difference and the central difference and the order of

the error associated with each. 6.3. Apply finite difference approximations to a simple partial differential equation (PDE). 6.4. Explicit and an implicit numerical scheme. 6.5. Implicit finite difference scheme applied to a simple linear pde leading to a set of linear

equations which are tridiagonal in 1d and pentadiagonal in 2d. 6.6. Structure of the pentadiagonal a-matrix in 2d for a given numbering scheme going from

(i, j) notation to m-notation where m is an ordered numbering. 6.7. Solution strategy for the non-linear single phase 2d pressure equation where the fluid

and rock compressibility are pressure dependent. 6.8. Discretised form of both the pressure and saturation equation for two-phase flow. 6.9. Impes solution strategy for the discretised two-phase flow equations.

7. Permeability upscaling. 7.1. 7.2. 7.3. 7.4. 7.5. 7.6. 7.7. 7.8. 7.9.

Reason for upscaling. Calculation ofeffective permeability in simple models by averaging. Numerical upscaling of single-phase flow. Effects of heterogeneity on two-phase flow. Limitations of applying single-phase upscaling to a two-phase problem. Steady-state, capillary-equilibrium upscaling for two-phase flow. 2-phase dynamic upscaling (the kyte and berry method). Upscaling around a well. Upscaling from the core-scale to the scale of a geological model, taking account of finescale structure and capillary effects.



65

SPECIALIZATION BLOCK: PE Module G11PE

PETROLEUM ECONOMICS Tutor J Fennema. Objectives 1. understand the economic concepts involved in project evaluation 2. understand the value of investments as defined within a fiscal system 3. evaluate risks associated with economic decisions Syllabus 1. Introduction. 1.1. 1.2. 1.3. 1.4. 1.5. 1.6.

General financial aspects of the petroleum industry. Nature and evolution of demand for oil. Evolution of oil supply. Role of the National Oil Company versus International oil company. Financial parameters or statistics reflecting performance of a petroleum company. Principal sectors of petroleum activity.

2. Evaluation methods. 2.1. 2.2. 2.3. 2.4. 2.5. 2.6.

Definition of an asset. Evaluation concepts and objectives. Book value and depreciation. Market value and models. Cash flow concept - “capex” and “opex”. Cash flow models.

3. Time value of money. 3.1. 3.2. 3.3. 3.4. 3.5. 3.6. 3.7. 3.8. 3.9.

Time Value. Compound Interest. Discounting. Present value of a single cash flow. Annuities. Price Inflation - Money of the day. Real terms, constant money, 2000 terms. Purchasing power. Conversion of money of the day to real terms and vice versa.

4. Project parameters. 4.1. Cash Flow Modelling - project screening and ranking, Maximum capital outlay, Payback 4.2. 4.3. 4.4. 4.5. 4.6. 4.7. 4.8. 4.9.

period, Terminal cash surplus, Profit to investment ratio (undiscounted). Discounted Measures of Value. Net Present Value (NPV) from project cash flows. Annual Capital Charge (ACC). Internal Rate of Return (IRR). NPV and IRR for acceleration projects. NPV, NPVI and IRR as screening criteria. NPV, NPVI and IRR as ranking criteria.

5. Government. 5.1. Importance of petroleum to government.

5.2. Resource Ownership. 5.3. United Nations Convention on the Law of the Sea. 5.4. Petroleum licensing. 5.5. Forms of licensing agreement. 5.6. Petroleum Development and government concerns. 5.7. Definition of “good oilfield practice”. 5.8. Purpose of a field development programme. 5.9. Flaring of methane. 5.10. Reservoir unitisation and describe its conceptual evolution. 5.11. Field abandonment. 5.12. Taxation - petroleum revenues. 5.13. Tax-reference price. 5.14. Corporate taxation of project - stand-alone and consolidated economic models. 5.15. Progressive and regressive taxes.

6. Sources of uncertainty and risk. 6.1. Geology - concept of exploration success. 6.2. Facilities – problems encountered in subsurface and surface. 6.3. Environmental issues pertaining to oilfield development. 6.4. Human failure. 6.5. Government – imposition of changes to project. 6.6. Describe an example of such a process. 6.7. Taxation policy and investment decisions. 6.8. Concept and implications of demand elasticity. 6.9. Function of spot markets and marker crudes. 6.10. Oil price uncertainty. 6.11. Market for gas. 6.12. Gas sales contract. 6.13. Gas pricing. 6.14. Exchange rate variation and influence on project economics. 6.15. Risk associated with borrowing money. 6.16. Partners – risks associated with partnerships.

7. Risk Management. 7.1. Sources of information to reduce uncertainty. 7.2. Transferring risk – financial instruments and commodity trading. 7.3. Diversification. 7.4. Joint ventures. 7.5. Scenario planning. 7.6. Relevant information in the context of decision-making. 7.7. Simple Decision Methods. 7.8. Sensitivity analysis. 7.9. Spider diagram. 7.10. Monte Carlo and Latin Hypercube sampling. 7.11. Mathematical Expectation. 7.12. Binomial probability Function to calculate expected value. 7.13. Preference Theory. 7.14. Decision Trees and value of information.



SPECIALIZATION: RESERVOIR EVALUATION AND MANAGEMENT Heriot-Watt University Modules:  Rock Mechanics, Geomechanics and Geophysics.  Well Testing and Production Logging. Same as PE  Reservoir Simulation. Same as PE  Modelling and Management.

Module G11RG

SPECIALIZATION BLOCK: REM ROCK MECHANICS, GEOMECHANICS AND GEOPHYSICS Tutors G Couples/J Somerville/C MacBeth/D Potter. Objectives 1. Understand the lab measurements of rock properties under stress. 2. Describe and represent the geometric characteristics of reservoirs. Explain development of reservoir shape in terms of deformation processes. 3. Understand the principles of core measurements, including sampling strategy, SCAL and the derivation of a, m and n. 4. Understand Pc and Saturation relationships and relative permeability measurement. 5. Understand the difference between imbibition and drainage curves and their measurement and interpretation. 6. Understand the need for corrections of petrophysical core measurements and the relation of core measurements to logs. 7. Understand impact of deformation on fluid flow, especially the role of faults and fractures. 8. Geomechanical approach to understanding flow in deformed rocks. 9. Reservoir Geophysics (basic principles). 10. Influence of rocks and reservoir fluids on seismic properties. 11. Seismic Attributes & Seismic Inversion. 12. Imaging and Resolution (tuning effects). 13. Correlation between Reservoir Characteristics & Attributes. 14. Acquisition & Processing (fundamentals, migration). 15. 4D Seismic. Syllabus 1. Principles and methods of laboratory measurements (Yield & post yield behaviour of rocks). 2. Rock Physics (Sonics properties of Rocks and Fluids). 3. Hydraulic fraccing process and the nature of well stability. 4. Rock compressibility as a drive mechanism. 5. Higher-order material descriptions (rheologies). 6. Rock mechanics principles. 7. Kinematic methods. 8. Understanding of core analysis report and core analysis techniques. 9. Strengths and limitations of poroperm data. 10. Derivation and meaning of parameters a, m, n.


69

11. Capillary Pressure/Saturation relationships and the measurement of relative permeability. 12. Basic rock typing concepts. 13. Relationship of core and log measurements. 14. Relate structural features to the basic rock mechanics concepts. 15. Relate fractures and their fluid flow consequences. 16. Relate faults and their fluid flow consequences. 17. Practical uses of structural geology. 18. Poroplastic behaviour phenomenon in basin compaction. 19. Seals formation and failure in overpressured basins. 20. Stress sensitive reservoir. 21. Influence of reservoir fluids on seismic properties. 22. Significance of seismic attributes. 23. Current seismic acquisition techniques. 24. Principles of seismic processing. 25. Quantitative seismic interpretation. 26. Assessment of the benefits of 4D seismic. Assessment methods  Examination: 80%  Coursework: 20%


70

SPECIALIZATION BLOCK: REM Module G11WP

WELL TESTING AND PRODUCTION LOGGING Tutor Shiyi Zheng. Objectives 1. Understand the diffusivity equation and the derivation of analytical solutions related to reservoir features (wells, fractures, aquifers). 2. Use the analytical solutions to describe fluid flow in a reservoir. 3. Calculate reservoir permeability in simple and complex reservoir geometries. Syllabus 1. Introduction to well testing. 1.1. 1.2. 1.3. 1.4. 1.5. 1.6. 1.7.

Reservoir depletion and the application of reservoir limit testing. Generalized form of the radial inflow equation. Dietz shape factors. Reservoir damage or improvement and skin factor. Brons and marting pseudo-skin. Arithmetic average in calculating equivalent permeabilities for layered systems. Effects of perforations on well production.

2. Pressure transient analysis. Objectives of exploration well testing. Derivation of diffusivity equation for radial inflow. Dimensionless versions of the linear de. Linearized radial flow equation for the line source boundary condition. Logarithmic approximation to the exponential integral solution of the line source. Solution. 2.6. Principle of superposition and its application to the specific case of build up testing i.e. The horner time function. 2.7. Construction of semi-log plots for basic ideal data sets and solve for basic reservoir parameters. Kh, skin. 2.1. 2.2. 2.3. 2.4. 2.5.

3. Late time boundary and depletion effects. 3.1. 3.2. 3.3. 3.4. 3.5. 3.6. 3.7. 3.8.

Geological features which present themselves as no-flow boundaries. Importance of fault detection by pressure analysis. Method of images and state the solution to the diffusivity equation for the system. Relationship between the logarithmic approximation and the semilog plot for MTR and LTR. Distance to boundaries. Identify the five basic elementary fault models log-log diagnostic plot and be able to use derivative type curves. Relationship between the ratio of the slopes of the MTR and LTR on the semilog plot and the angle of intersection of faults. Identification parallel faults.

4. Distributed pressure measurements. 4.1. 4.2. 4.3. 4.4.

RFT tool. Analysis of a pretest record. Supercharging and supercharging index. RFT data presentation.


71

4.5. Benefit of the new generation MDT device.

5. Exploration applications of distributed pressure measurements 5.1. 5.2. 5.3. 5.4. 5.5. 5.6. 5.7. 5.8.

Nature of an unproduced reservoir at gravity-capillary equilibrium. RFT gradient intersection coincide with the free water level. Paleo-contacts and the concept of residual oil. RFT indication of water gradient in a trapped oil zone. Detection of tar mats. Effect of oil wet rock on a RFT survey. Geological significance of a perched contact and its recognition on a RFT survey. Tilted contacts and dynamic aquifer effects.

6. Field development applications of distributed pressure measurements Problem of discrimination of supercharged points. Effect of vertical component of flow on the pressure gradient. Theory of single phase flow Interpretation of gradients in simple multiphase flow situations. Vertical pressure equilibrium. Partially communicating faults and inter-block Pls. Relation between fault multipliers in a simulator and intrinsic fault transmissibility indices. 6.8. Use of compartmentalized material balance for RFT interpretation. 6.9. Importance of production logging data as a complement to RFT data. 6.1. 6.2. 6.3. 6.4. 6.5. 6.6. 6.7.

7. Reservoir management 7.1. 7.2. 7.3. 7.4. 7.5.

Production logging surveys. Integration of well test and core analysis studies with PLT surveys. Importance of the reservoir monitoring. Understand the selective inflow performance (SIP) technique. Sign of infill drilling of injection wells.



72

SPECIALIZATION BLOCK: REM Module G11RS

MODELING AND MANAGEMENT Tutor P Corbett/M Christie. Objectives 1. Understand the concept and basis of geomodelling (includes geostatistics and equiprobable realisations). 2. Understand the workflow in constructing a geomodel. 3. Understand the role of integration in geomodelling. 4. Understand reservoir management. 5. Understand uncertainty in geomodelling and how it is treated. Syllabus 1. 2. 3. 4. 5. 6.

Gain a familiarisation of geological modelling techniques. Understand the role of outcrop databases. Understand the use and limitations of geological geostatistical models. Understand challenges of data integration in reservoir studies. Gain awareness of current mature field management techniques. Understand the various techniques for uncertainty prediction and reduction.



73


SPECIALIZATION: PETROLEUM GEOSCIENCES Heriot-Watt University Modules:  Stratigraphy and Reservoir Quality.  Petroleum Systems.  Petroleum Geophysics.  Geomechanics and Flow Mechanics.


74

SPECIALIZATION BLOCK: PETGEO STRATIGRAPHY AND RESERVOIR QUALITY

Module G11ST Tutor H. Lever

Objectives 1. Demonstrate how the principles of stratigraphy can be used to understand the physical characteristics of strata in a petroleum basin 2. Demonstrate how post-depositional diagenetic changes in rocks affect the hydrocarbon reservoir quality. Syllabus 1. Know the basic characteristics of carbonate systems and their evolution 2. How carbonate sedimentation differs from clastic sedimentation in response to relative sea level change 3. The main features of carbonate sequence tracts 4. The characteristics of key surfaces as recognised in core, seismic and wireline logs 5. Case examples of mixed carbonate-clastic systems 6. An introduction to biostratigraphy as used in the petroleum industry 7. Know the drivers for diagenesis and the petrophysical consequences, particularly for clastic rocksUnderstand the concepts of seismic and sequence stratigraphy and apply them to realistic datasets. Learning outcomes: 1. • Understand the sequence of formation of a basin and the rocks and rock sequences contained within it, for both siliciclastic and carbonate dominated systems 2. • Be able to integrate geological and geophysical data to determine the rock sequences within the basin 3. • Understand how diagenesis affects rock properties

Assessment Methods  Examination: 80%  Coursework: 20%


75

SPECIALIZATION BLOCK: PETGEO Module G11PS

PETROLEUM SYSTEMS Tutor Andy Aplin (Newcastle University) Objectives 1. Understand the thermal and hydrocarbon characteristics of a petroleum basin. Syllabus 1. 2. 3. 4. 5.

Understand the thermal and pressure evolution of petroleum basin systems. Be able to interpret a simple basin model. Know the geochemistry and types of hydrocarbons and their modes of formation. Know the time/temperature conditions for hydrocarbon generation and maturation. Understand what drives and controls hydrocarbon migration and entrapment.

Learning outcomes: 1. Understand the sequence of formation of a basin and the rocks and rock sequences contained within it 2. Be able to integrate geological, geophysical and geochemical data 3. Determine the value of a prospect. Assessment Methods  Examination: 80%  Coursework: 20%


76

SPECIALIZATION BLOCK: PETGEO Module G11GP

PETROLEUM GEOPHYSICS Tutor Dr. Asghar Shams Objectives 1. Introduce Geophysical methods for hydrocarbon exploration and production 2. Focus on reflection seismic methods (2D & 3D) 3. Review reflection seismic interpretation techniques & applications Reservoir Geophysics (basic principles). Syllabus 1. Geophysical Reconnaissance Methods 2. Seismic Acquisition and Overview 3. Reflection seismic processing 4. Geophysical Data Management 5. Rock Physics 6. Seismic Interpretation basics 7. Making maps 8. Seismic Stratigraphy 9. Seismic Structural Geology 10. Well Planning & Drilling Understand the influence of reservoir fluids on seismic properties. Learning outcomes: 11. Prioritisation of geophysical techniques according to E&P phase, basin setting, data availability, budget & timelines 12. Basic seismic interpretation skills for sedimentary architectures, structures and map making 13. Integration of reflection seismic and well data for existing well control and new well planning and drilling Explain the processes of brine, oil, and gas movements in hydrocarbon reservoirs and basins Assessment Methods  Examination: 80%  Coursework: 20%


77

SPECIALIZATION BLOCK: PETGEO Module G11GM

GEOMECHANICS AND FLOW MECHANICS Tutor Sebastian Geiger Objectives 1. To understand and quantify the movement of fluids (brine, oil, gas) in the subsurface over timescales ranging from geological to human 2. To understand how the fundamental principles of geomechanics predicts compaction, folding, faulting and fracturing on the basin to the reservoir scale 3. To be able to apply the fundamental physics of flow- and geomechanics to the challenges encountered in assessing hydrocarbon exploration and appraisal issues Understand the lab measurements of rock properties under stress Syllabus 4. Fundamental physics of single- and multi-phase fluid flow in porous media 5. Principles of well-testing to assess subsurface fluid flow 6. Challenges of quantifying flow properties in geological formations 7. Fundamentals of stress and strain and failure criteria 8. Geomechanics and Structures in Basin Settings 9. Poroplasticity and its consequences for porosity and permeability evolution 10. Rock mechanics testing in the laboratory 11. Introduction to Geomechanical Simulation of geological structures 12. Characteristics of Faults, Folds and Fractures, and their relationship tomechanics and fluid flow 13. Fundamentals and practicalities of predicting fluid flow in deformed porous rocks Understand how measurements are obtained in the laboratory (Yield & post yield behaviour of rocks). Learning outcomes: 14. Explain the processes of brine, oil, and gas movements in hydrocarbon reservoirs and basins 15. Know where and why rock deformation takes place Explain the fluid flow impacts of rock deformation 16. Understand the challenges in setting up models and running simulations for flow, geomechanics, and coupling between these Assessment Methods  Examination: 80%  Coursework: 20%


78


SPECIALIZATION BLOCK TIMETABLE January-March 2015


79

Date

Activity

Remarks

January 9th, 2015

Enrolment process

Petroleum Engineer, Reservoir Evaluation and Management, Petroleum Geosciences

January 12th – March 20, 2015

Regular classes and tutorials

Heriot Watt University Campus at Edinburgh

April 13th – May 8th, 2014

Exams

British Council at Madrid


80


BLOCK III: FIELD TRAINING BLOCK Oct-Nov 2014 & Mar-Apr 2015    

Geology Field School. Basic Overview Block Drilling Field School Production Field School HSE School & Certifications


81

FIELD TRAINING BLOCK GEOLOGICAL FIELD SCHOOL

Module BOB 2 Collaborator: GESSAL

The GESSAL group (GESSAL E&P & GESSAL GAS) is a group of technical consulting companies focused on geological and geophysical services for subsurface exploration and research: hydrocarbon exploration and underground storage (gas & CO2). Its services are supported by up-to-date technology used in: Regional Exploration Evaluation, Basin Analysis, Petroleum System, Prospect Generation and Evaluation, Geophysical and Geological Interpretation, Log Analysis, Petrography Interpretation, Geological and Geochemical Modelling, Structural and Stratigraphic Analysis, Integral Development of Exploration Programs, Reservoir Evaluation, Data Management, Geological-Geophysical Computer Applications and Training Courses. Objectives 1. Understand the basic review of the regional setting of the Basque-Cantabrian Basin Petroleum System. 1.1. Regional Stratigraphy. 1.2. Tectonosedimentary evolution. 1.3. Basque-Cantabrian Basin Petroleum System. 1.4. Hydrocarbon Discoveries and Play Concepts.

2. Understand the basic concepts of petroleum system on the analysis of outcrop observation and subsurface data of the Basque-Cantabrian Basin. 2.1. Outcrop recognition of the Basque-Cantabrian Basin Stratigraphy. 2.2. Understand the regional structure: Extensional and compressional features; Salt Tectonics. 2.3. Understand the subsurface data (wells, seismic, geochemistry, etc) with outcrops analogs. 2.4. Characterization of Source rocks, Reservoirs, and Seals. 2.5. Characterization of Traps and Structures. 2.6. Hydrocarbon generation, migration and preservation processes. 2.7. Ayoluengo Oilfield.


82

Syllabus 1. Basque-Cantabrian Basin: General Stratigraphy and Tectosedimentary Evolution. 1.1. Palaeozoic Rocks: Carboniferous. 1.2. Triassic: Buntsandstein, Muschelkalk, Keuper and Imon Fm. 1.3. Jurassic.

a) Marine: Lias - Dogger. b) Continental - Marine: Purbeck Facies. 1.4. Cretaceous.

a) Lower Cretaceous: Purbeck, Weald and Utrillas Formations. b) Upper Cretaceous. 2. Source Rocks. 2.1. Carboniferous. 2.2. Jurassic: Lias and Dogger. 2.3. Purbeck Facies. 2.4. Lower Cretaceous.

3. Reservoirs, Traps and Seals. 3.1. Triassic. 3.2. Jurassic Lias and Dogger. 3.3. Purbeck Facies. 3.4. Lower and Upper Cretaceous.

4. Concepts: 4.1. Carbonate platform. 4.2. Siliciclastic platform. 4.3. Shoreline facies. 4.4. Deltaic systems. 4.5. Continental facies: Alluvial, fluvial: braided and meandering systems, evaporate and lacustrine deposits. 4.6. Salt related tectonics (halokinetic processes). 4.7. Rifting stages. 4.8. Alpine Tectonics

Main Exercises and Tutorials Discussion: Characterization of source rocks for gas and oil, reservoirs and seals. Bunt Play, Duero Basin Play and Ayoluengo Field source rock. Structure analysis and complex salt tectonics areas. Age of structures and time of hydrocarbon generation. Ayoluengo Field reservoir, Ayoluengo Play, Stratigraphic Play and Aptian-Albian gas play (Duero Basin Play). Analysis of the basin margin section in comparison with a subsiding trough. Structural analysis of the Montorio Folded Belt. Hontomin Play. Carboniferous and Mesozoic source rock-reservoir-seal relationships, characterization of traps and structures, analysis of hydrocarbon generation and migration processes, age of structures and time of generation, play concepts. The stops will provide a good mix of panorama overlooks, detailed outcrop analogues, and examination of seismic records and well log data.


83

Program Day 1. Carboniferous, Triassic and Jurassic of the Polientes Trough. Stops in BarrueloBrañosera: Stephanian facies, Carboniferous source rock for gas, Early Rift Stage, Bunt facies, Navajo 1 well, Bunt reservoir potential. Stops in the access road to Camino-Camino: Muschelkalk facies, Keuper facies, Navajo 1 well, Inter-Rift Stage, Lias facies, Cadialso 1 well, carbonate reservoirs and seals, Lias source rock for oil, thermal maturity. Day 2. Polientes Trough Jurassic and Early Cretaceous. Stratigraphy and tectonics. Stops in San Andrés: Dogger, Cadialso 1 well, Jurassic carbonate reservoir potential. Stop in Barcena del Ebro: Bay of Biscay Rifting Stage, Purbeck facies continental to marine transitional, Ayoluengo wells, Siliciclastic reservoir potential and seals, source rock for gas, fracture patterns. Stop in Olleros de Paredes Rubias: Rifting to Drifting Stage, Middle Cretaceous fluvial facies, Cantonegro 1 well, reservoir potential, source rock for gas. Stop in Aguilar de Campo, carbonate lacustrine facies, Abar 1 well, Stratigraphic lateral changes, source rock for gas and reservoir potential, seismic revision, Mesozoic extension–Alpine compression overprint, genesis and evolution of Mesozoic and Alpine traps. Day 3. Marginal area. Stratigraphy and tectonics. Ayoluengo Oilfield. Stop in Humada: Faults of Ubierna and Humada, folding area of Montorio. Stop in Amaya: Margin type section, Jurassic dolomite, Hontomin wells, reservoir potential, Lias source rock, thermal maturation. Stop in Basconcillos del Tozo: Oil shows, generation and migration concepts, “timing”, etc. Stop in Ayoluengo Oilfield. Day 4. Poza de la Sal Diapir: Basics on salt tectonics, evaporite different behaviour in outcrops and subsurface, old halite mines. Structural cross- sections from Montorio Folded Belt to the Duero Cenozoic foreland basin. Day 5. Ayoluengo Oil Field Reservoir: Lower Purbeck: Corvio member and Fm Aguilar. Weald meandering and braided facies. Final evaluation test. Textbooks and Consulting Books  Field Trip Guide Gessal.  Petroleum System of the Basque Cantabrian Basin (South-western Sector).


84

FIELD TRAINING BLOCK DRILLING FIELD SCHOOL

Module DRIL Collaborators

Crescent. Oklahoma USA Objectives 1. Observe the technology used in a drilling rig, drill string, bits, drilling tools, power generation system, hoisting system and rotation system. 2. Show the mud system, pumps, pits, screen shakers, and solids control equipment. 3. Identify the different components involved in the BOP stack, Manifold, Flare, Vent. 4. Analyze the drilling control room and alarm systems. See the Geological cabin, data gathering and Data transmission. 5. Observe typical drilling rig operations: Casing run, Cementing, Logging, Run Completion, Casing Perforation, Coring, etc. Itinerary 1. Introduction to drilling safety considerations. 2. Visit different types of drilling rigs: Mechanical, Semi-Automatic and Automatic. Recognize the main systems and the different components of each type of rig. Special attention to the Power generation, Hoisting, Rotation, BOP´s and Manifold system. 3. Observe and understand the run-in-hole and pool-out-of-hole manoeuvres. 4. Describe the roles of the tool pusher, rough necks, company man and derrick man. 5. Look at the mud system components. 6. Mud control in the field. Visit a Mud engineering company and description of the types of mud by section. Disposal of the mud residues. 7. Visit to a material and equipment drilling yard. Observe casing running equipment, centralizers, casing shoes, hangers, wellheads. 8. Understand a cementing operation. Observe the Surface layout of a cementing operation. 9. Observe a Logging operation. Log quick interpretation in the field. Determination of intervals to be perforated. 10. Visit a Completion string running. Observe the well status, equipment, tubing, XMass trees, etc. 11. Visit a Completion company. Explanation of tools, packers, landing nipples, fishing tools, milling tools. Observe coring equipment 12. Observe the different measurements taken and its interpretation. 13. The evaluation of the module is a presentation of a system or a specific topic by the teams. The teams and the subject are distributed the day before the last.


85

FIELD TRAINING BLOCK Module PROD

PRODUCTION FIELD SCHOOL Collaborators Crescent. Oklahoma USA

Objectives 1. Observe field operations, equipment spud, pulling and work over. 2. Evaluate the needs for roads to the site, well site dimensions, wellheads and production equipment. 3. Recognize the instrumentation and monitoring systems in the field (scada). 4. Visit the field facilities; identify the different treatment units and the installations used for secondary recovery. 5. Analyze the different roles of the personnel involved in field work. 6. Observe a metering unit; analyze the drilling control room and alarm systems. Itinerary 1. Visit to a production warehouse or material and equipment yard. Observe the equipment used in the wells, tubing, wellheads, accessories. 2. Visit to a field in production. General description of the gathering facilities. Observe operating parameters, pressures, rates, temperatures, load in rods, etc. Observe sampling of the wells. See the data gathering, transmission and follow up. 3. Visit to an oil treatment and water injection facilities. Observe the different equipment and their control. See power consumption, chemical injection, and related utilities. Observe manning of the installations. 4. Visit to a gas compression plant. Observation of operating parameters of the treatment process, manifold, compressors, chemical protection, gas quality and quantity measurement. See the related utilities. Observe the manning of the installations. 5. Loading site visit, tanks, metering systems, and operations description. 6. Laboratory measurements. 7. Visit to an ESP’s, PCP’s and rod sucker pump service company yard. Explanation about internal mechanisms of the pumps, their installation, retrieval and maintenance. 8. Visit a Pulling and Workover unit. Observe and understand the actual operation. Observe the tools and the equipment at work. 9. The evaluation of the module is a presentation of a system or a specific topic by the teams. The teams and the subject are distributed the day before the last.


86

FIELD TRAINING BLOCK Module HSE

REPSOL HSE SCHOOL Collaborators Repsol Corporate and E&P HSE Teams The course is taken during a week, in Mostoles, normally after the HWU and before the Drilling and Production Schools but subject to change of schedule. The school is a mixture of theoretical classes and practical case studies. Objectives 1. Learn and understand the main HSE rules and management principles that Repsol applies to all the activities in the company. 2. Learn the Upstream hazard principles and Management system that Repsol applies to all the E&P activities. 3. Learn the Environmental Impact Assessment in Repsol as a company. 4. Learn the Social and Environmental Impacts in Upstream operations. 5. Learn about the Repsol HSE culture, corporate responsibility, incident management system, oil spill modelling and the personal protective equipment used in drilling and production operations. Itinerary 1. Repsol HSE Policies. Risk Management in Repsol. 2. Upstream Hazard Principles. HAZID. Upstream Hazard Management –Bow Tie. BowTie practical exercise. 3. Environmental impact Assessment in Repsol. Social and Environmental Impacts in Upstream operations. Case studies: Jungle operations (Block 16, Ecuador). 4. Corporate Responsibility. Incident Management GAMA. 5. Oil Spill Modelling + practical exercise (external provider). 6. Accident Investigation. Upstream application (HGI) 7. Case Study: Applied HSE in Seismic projects. 8. Case Study: Applied HSE in Drilling projects. 9. Safety and Environmental Management Systems in Repsol. Upstream HSE system and relevant procedures. 10. Case Study: Applied HSE in Production projects. 11. HSE Culture and stop Program (Personal Protective Equipment). A test will be done to evaluate the course results.


87

FIELD TRAINING BLOCK HSE CERTIFICATES FIELD SCHOOL

Module HSE

Objectives 1. Obtain the main certificates needed to obtain access to the Repsol Installations worldwide (Seismic Acquisition, Drilling Operations, Production Operations, Offshore operations, Helicopter Transport, H2S hazard induction) Itinerary 1. Bosiet Certificate (Basic offshore safety induction and emergency training- include HUET & Ebs). 2. H2S Induction course.


88


BLOCK IV: TEAM PROJECT BLOCK CSFR Madrid May to July 2015


89

Overview The purpose of the team project is to develop and consolidate the level of knowledge acquired in class through a multidisciplinary work team. Students will use real data from an E&P company database, and will establish, based on the information provided, a geological model, build up one or more development scenarios, suggest different future exploration strategies and recommend commercial options, within a given economic context and environmental scenario. Specific project goals will be established in the Project Guide later on. The project is conceptually simple and involves the use of pre-selected data. Students are not expected to find complex solutions, but to consolidate basic concepts and knowledge within the framework of the generally accepted principles of exploration and production. Use of real E&P data The data will be taken from a field, in which the petroleum system can be easily established. The database is extensive and complete, and covers all relevant aspects in exploration and production. It includes:  Geological reports.  Fluids Laboratory analysis reports (PVT).  Seismic data.  Surface facilities schematics.  Drilling reports.  Production history.  Well logs.  Previous Field Development  Core analysis. Plans.  BHT and BHP measurements.  RFT data. This data is delivered in several formats in order to get the students familiarized with a wide range of sources during the project, and face similar challenges as they would in their professional life. Objectives Students will have to deliver by the end of the block, their own development plan introducing the technical and economic strategy to increase the recovery factor from the field. By the end of the project, each team should have delivered a report and make a presentation to a board of experts acting like a board of directors from the company. The proposed development plan shall include:        

Description of the regional geology and petroleum system. Maps in depth and time. Estimation of volumetric: Oil in place, Oil Water Contact, Recoverable Reserves. Static model: Reservoir properties. Dynamic model: Reservoir simulation. Drilling campaign. Surface facilities required. Production decline analysis.


90

 Development strategy.  Economical evaluation. The project lasts 10 weeks. Multidisciplinary teams The students are organized in multidisciplinary teams, according to their background, specialization and professional experience as: Geologists, Geophysicists, Reservoir Engineers, Drilling Engineers and Production Engineers. The team must choose a “Team Leader” who will be in charge of the coordination of all the members’ activities as well as acting on their behalf at special meetings with consultants and coordinators. The different tasks related to the completion of the project shall be reassigned within the team thus each member of the group is responsible for a different area of investigation. Assessment By the end of the project, each team will present their results to a Board of Experts acting like a Board of Directors from an E&P company. Their grades weight 50% of the final mark from the block and will be the same for all team members. The 30% of the final mark will be given by the coordinators of the project, who will continuously evaluate the performance of the teams. They will also hold preliminary evaluation meetings through the project. Finally, 20% of the final mark will be given by each student, evaluating the commitment and results obtained by their team members. Technical software The software used for seismic interpretation, property modelling, reservoir simulation, drilling plan, economic analysis, etc. available in CSFR is the same that is used in Repsol in its everyday operations. As the licenses available are intended for academic purposes only, the use of the software specific for the project will be limited to the project timeframe. Specialists from Repsol, and sometimes from the software builders, will teach the proper use of these tools in tutorials. Students will be recommended to take the tutorials, but the final decision on this recalls on each group. The offer of places for these tutorials will be limited on the number of licenses available in each case. For instance, GeoFrame (for static modelling) will be available for two users per group (Geologist and Geophysicist) but Landmark (Drilling) will be available only for one user per group. Tutorials Apart from training in specific tools for use in the project, other key areas will be developed during this term. They will be taught in one-week tutorials. These tutorials will not be assessed by the means of an examination, but will be considered in the final mark for the project.


91


TUTORIALS Team Project Block


92

Activity Regional Settings and Description of the Basin Correlations (WellPix)

Tutor H. Gonzalez F. Molina

Reservoir Engineering Data Room

E. Izaguirre

Seismic Interpretation (CHARISMA)

J. Franques

Seismic QA/QC, Mapping and Gridding

A. Arrieta

Seismic Time to Depth Conversion/Synthetics

A. Arrieta

MBAL - PROSPER - GAP (Integrated Production Management)

Petex

Basic Drilling Technology

Petroskills

Drilling Planning: Compass, WellPlan

R. Martin

Petrophysical Applications Surface Facilities Modelling: Hysys Phase I Meeting

Khalid El Jaafari J.E. Gomis AST/JIT

Property Modelling with Petrel Offshore Installations

J. Prieto Fanjul M. Moreu

Cost Estimation

C. Lopez

Reservoir Simulation: ECLIPSE

F. Mustieles

Economics

G. Gonzalez

Phase II Meeting

AST/JIT

HSE Fundamentals for Offshore / Onshore Projects

O. del Rio

Project Dissertation

Board

Project Review

AST/JIT


93

TEAM PROJECT BLOCK Tutorial SOFT SKILLS

COMPETENCIES (SOFT SKILLS) Tutor Personal Development Soft Skills Objectives To develop competencies and train on personal skills in order to perform better in the workplace; either individually or in teamwork. Encouraging self-development and professional career growth. Program subject to changes in topics and schedule. Contents 1. 3. 4. 5. 6. 7. 8.

Self-development: learning and integration. Organizing own timetables for work. Interpersonal communication. Reports handling (do report; present reports). Team work and meetings. Decisions making. Negotiating.


94


PROJECT TIMETABLE May-July 2015


95

Master in Oil and Gas Exploration and Production Team Project Block - Preliminary Schedule Program 2014-2015

May June July Activity Tutor 18 19 20 21 22 25 26 27 28 29 1 2 3 4 5 8 9 10 11 12 15 16 17 18 19 22 23 24 25 26 29 30 1 2 3 6 7 8 9 10 13 14 15 16 17 20 21 22 23 24 Personal Development Soft Skills Project Kick Off Master Directors Regional Settings and Description of the Basin M.Esteban Well logs, data loading and correlations in Wellpix and IP K. El Jaafari Reservoir Engineering ( PVT, MDT and Well Test) E. Izaguirre Data loading & Well tie to seismic A. Arrieta Seismic Interpretation in Carisma J. Franques Mapping and Griding & Time to Depth Conversion J. Franques / A. Arrieta Basic Drilling Technology Petroedge Gas Conditioning & Surface Facilities Modelling J. Gomis Drilling Planning: Compass, WellPlan, Stresscheck R. Martin Petrophysical Applications in IP K. El Jaafari Integrated Production Management (MBAL - PROSPER - GAP) Petex Phase I Meeting Master Directors Property Modelling in Petrel J. Prieto Fanjul Static Model must be done Offshore Installations M. Moreu QUE$TOR Offshore C. Lopez Reservoir Simulation in Eclipse F. Mustieles Dynamic Model must be done Economic Evaluation G. Gonzalez Phase II Meeting Master Directors HSE Fundamentals for Offshore Projects Oscar del Rio Draft FDP delivery Final FDP delivery Project Dissertation Evaluation Board Project Review Master Directors Soft Skills and Assignments Human Resources DP&O Closing Ceremony All

Geoscientist

Production Eng.

Milestone

Reservoir Eng.

Drilling Eng.


96

Syllabus Master Repsol

Recommend Documents