gas exploration and production

Masters Programme in

Oil and Gas Exploration and Production

Móstoles, Madrid. September 2010 ‐ July 2011

Centro Superior de Formación Repsol Masters Programme in Oil and Gas Exploration and Production

Index

Introduction 2 Overview 3 Terms and Holidays periods 3

Basic Overview Block 5

BOB 1 A/C Exploration Principles Basic Petroleum Geology and Structural Geology 6 BOB 1B Exploration Principles Basin Analysis and Petroleum Systems 8 BOB 2 Geology Field School 10 BOB 3 Well Logging 13 BOB 4 Drilling Engineering 15 BOB 5 Geophysics 17 BOB 6A Reservoir Geology and Characterisation 21 BOB 6B Reservoir Engineering 24 BOB 6D Well Testing 27 BOB 6E Reservoir Simulation 29 BOB 7A Subsurface Production Technology 31 BOB 7B Surface Production Technology 34 BOB 8 Economic Evaluation 36 BOB 9 Risk Analysis 40 BOB 10 Offshore Structures 42 Timetable 44

SPECIALISATION BLOCK 45

General Information about the School 46 Specialisation in Petroleum Engineering 47 Specialisation in Reservoir Evaluation and Management 48 Specialisation in Geoscience for Subsurface Exploration, Appraisal and Development 50 Guidance on Assessment 52

FIELD TRAINING BLOCK 53

Drilling Field School 54 Production Field School 54

TEAM PROJECT BLOCK 55

Overview 56 Team Project Timetable 64

INTRODUCTION

MSc. in Oil and Gas Exploration and Production

This postgraduate programme has been designed to train young professionals who are considering pursuing a career 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 that are active in this field, professionals invited by Repsol to the programme, and/or personnel from other E&P companies under a cooperation Agreement with Repsol.

They should have an excellent basic technical background before joining CSFR. The education they receive during this Master Programme will help them familiarise with the necessary tools and acquire key skills that will enable them to carry out their professional activities in the most efficient way.

Exploration and Production activities have a strong international character, thus the programme in Madrid is fully and exclusively taught in English. CSFR teaching staff is composed of foreign university teachers and highly qualified petroleum industry professionals, drawn mainly from Repsol. The section of the programme called Specialisation Block is taught in the Heriot‐Watt University. (Edinburgh, United Kingdom)

The programme lasts ten months. It starts on September 6th, 2010 and finishes on July 8th, 2011. 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.

Specialisation Block

Its purpose is to go in depth into specific areas of the disciplines involved in an E&P project (geology, geophysics, and engineering) according to the students' preferences and their previous academic qualifications. The students will be integrated into the relevant programmes which are 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 Specialisation. Those who intend to specialize in Petroleum Geology or Geophysics will receive in‐depth training in these fields by means of programmes designed specifically for this purpose.

CENTRO SUPERIOR DE FORMACION 2

INTRODUCTION

Field Training Block

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

Geology Field Trip (takes place during the Basic Overview Block).

Drilling Field Trip.

Production Field Trip.

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 reservoir, which will be taken as a starting point.

Use of technologically advanced software tools.

Tutorial support provided by external consultants.

Presentation of conclusions and results by phases and then upon project completion.

Overview

Lecture period: September 2010 ‐ July 2011

Instruction begins: September 6th 2010

Last day of lectures: July 6th 2011

Closing ceremony: July 8th 2011

Length: 10 months

Academic Hours: 1515 hours

Terms and Holidays periods

Period Start date Finish date

Basic Overview Block September 06th 2010 December 17th 2010

Christmas Holidays December 18th 2010 January 02nd 2011

Specialisation Block* January 3rd 2011 March 13th 2011

Eastern Holidays April 21st 2011 April 22nd 2011

Field Schools ** **

Team Project May 2nd 2011 July 5th 2011

* Subject to modifications by HWU. Examinations date to be determined. ** To be confirmed.


INTRODUCTION

Basic Overview Block

Code Module Lecturer

IGRYPF Introduccion General a RYPF y a la Industria DG PyO (in Spanish)

BOB 1A/C Basic Petroleum Geology and Structural Geology Alan Chambers

BOB 1B Basin Analysis and Petroleum Systems Santiago Quesada

BOB 2* Geology Field School Gessal

BOB 3 Well Logging Jesus Sotomayor

BOB 4 Drilling Engineering John Ford

BOB 5 Geophysics Marcelo Benabentos

BOB 6A Reservoir Geology and Characterisation Patrick Corbett

BOB 6B Reservoir Engineering Emilio Carro

BOB 6D Well Testing Elena Izaguirre

BOB 6E Reservoir Simulation Francisco Mustieles

BOB 7A Subsurface Production Technology David Davies

BOB 7B Surface Production Technology Enrique Gomis

BOB 8 Economic Evaluation Gerardo Gonzalez

BOB 9 Risk Analysis Antonio Suarez

BOB 10 Offshore Structures Seminar Manuel Moreau

Specialisation Blocks


PE Petroleum Engineering Several

REM Reservoir Evaluation and Management Several

GG Petroleum Geology Several

GPH Petroleum Geophysics Several

Field Training Block


BOB 2* Geology Field School Gessal

PROD Production Field School SENDA Team

DRIL Drilling Field School SENDA Team

Team Project Block


TEAM Several Several



BASIC OVERVIEW BLOCK Madrid. September ‐ December 2010

BASIC OVERVIEW BLOCK

BOB 1 A/C Exploration Principles Basic Petroleum Geology and Structural Geology

Lecturer

Dr. Alan Chambers works at Repsol Exploracion as a specialist in Structural Geology. He received a BSc. in Geology from Durham University, U.K., as well as a MSc. in Structural Geology and a PhD from Imperial College. He has spent several years with: the Earth Science Resources Institute, Lasmo and Texaco (as a Consultant); Mobil North Sea Ltd (working in deepwater areas of the Atlantic Margin); and Union Texas Petroleum (Central Mediterranean Area).

Syllabus

1. Classification of Rocks.

1.1. Igneous (intrusive, extrusive, composition, basic mineralogy, basic rock types, seismic expression, global distribution).

1.2. Sedimentary. a) Clastics, weathering‐erosion‐transport‐deposition‐burial, texture, layering,

sequences, seismic expression. b) Biogenic, carbonate factory, organisms through time, classification, rock types,

ramps, rimmed platforms, diagenesis, and seismic expression. c) Chemical sediments, mainly evaporites. Seismic expression.

1.3. Metamorphic (pressure, temperature, basic minerals, rock types). 1.4. Extra‐terrestrial (meteorites and craters).

2. Stratigraphy

2.1. Superposition. 2.2. Horizontality. 2.3. Cross‐cutting. 2.4. Inclusions. 2.5. Lateral continuity. 2.6. Faunal succession. 2.7. Relative age, absolute age, the geologic time scale. 2.8. Gaps in the geological record (unconformities). 2.9. Accommodation space, subsidence and sea‐level change. Sequence stratigraphy.

3. Reconstructing Geological History from outcrops, from seismic and wells.

4. Plate tectonics ‐ tectonic settings to structural trapping configurations.

5. Rock failure.

6. Structural styles and trapping geometry (contraction, strike‐slip, extension, gravitational collapse (and ductile layers ‐ salt), their seismic expression and case histories.

7. Stratigraphic traps (pinchout, truncation, diagenetic, hydrodynamic).

8. Prospect mapping.

Main Exercises and Tutorials

Exercise 1: Maturity Model. Exercise 2: Structural Interpretation in Petroleum Exploration.



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.



BOB 1B Exploration Principles Basin Analysis and Petroleum Systems

Lecturer

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.

Syllabus

1. The Nature of Hydrocarbons.

1.1. Carbon and Organic Matter. 1.2. Crude Oil, Natural Gas and others.

2. Sedimentary Basins.

2.1. Mechanisms of Basin Formation. 2.2. Classification of Sedimentary Basins. 2.3. The Sedimentary Basin Fill.

a) Sediment Supply, Subsidence and Basin Fill. b) Starving and Overfeeding. c) Up‐ and Out‐building (aggradation and progradation).

2.4. Sedimentation Rates and Organic Matter. a) Instantaneous and average rates. b) Organic Matter: Supply and Preservation.

3. The Subsurface Environment.

3.1. Subsurface Waters, Temperatures and Pressures. 3.2. Diagenesis.

a) Compaction. b) Chemical Diagenesis. c) Differential Compaction.

3.3. Fluid flow (Meteoric, Compaction, Thermobaric, Convection). 3.4. Pore Pressure. 3.5. Thermal History.

4. Introduction to the Elements of the Petroleum Play.

4.1. The Petroleum Charge: Source, Migration and Preservation. a) Source Rocks, Quality and Maturation. b) Expulsion and Migration Pathways, Timing. c) Degradation of oil in the Reservoir.

4.2. The Reservoir. a) Reservoir Types, Geometry and Continuity. b) Porosity, Permeability, Modifications and Pressures.

4.3. The Trap. a) Types of Traps and Statistics.

4.4. The Seal. a) The Mechanics of Sealing. b) Geometry of the Trap and Sealing Requirements.

5. Analysis of the Petroleum System.

5.1. Basin Modelling Techniques. 5.2. Tutorial on Maturity Model.




6. Structural Styles.

6.1. Overview of the Main Structural Styles (Extensional, Compressional, Strike‐slip and Salt Tectonics).

6.2. Introduction to Structural Geometries and Sedimentation of Rift Basins. 6.3. Tutorial on the Exploration Process, from Play Concept to Discovery.


Exercise 1: Maturity Model.

Exercise 2: Exploration Process, from Play Concept to Discovery.

Software Applications

BasinMod.


“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.


BOB 2 Geology Field School

Lecturer

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).

GESSAL was created in 1987 and is based in Madrid. It uses advanced scientific technology to offer a wide range of services. It is made up of a group of professionals, chiefly geologists, geophysicists and computer specialists, with great expertise in subsurface resource exploration.

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 Programmes, Reservoir Evaluation, Data Management, Geological‐Geophysical Computer Applications and Training Courses.

GESSAL group has been involved, as a consultancy company, in Hydrocarbon Exploration, Natural Gas, CO2 and High‐Activity Radioactive Waste Storage, Hydrogeology and Mining Investigation for firmly‐rooted companies, involved in Subsurface Research (Repsol, CTR, CEPSA, ENAGAS, Gas Natural, ENRESA, ENDESA, IBERDROLA, UNION FENOSA, SOCOIN, Ministerio de Industria Turismo y Comercio de España, IGME, Petroleum Oil and Gas, NUELGAS, TEREDO, ESCANA OGP, SHESA, ESCAL UGS, YCI, etc.)

Objectives

1. Understand the basic review of the regional setting of the Basque‐Cantabrian Basin Petroleum System.

1a. Regional Stratigraphy. 1b. Tectonosedimentary evolution. 1c. Basque‐Cantabrian Basin Petroleum System. 1d. 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.

2a. Outcrop recognition of the Basque‐Cantabrian Basin Stratigraphy. 2b. Understand the regional structure: Extensional and compressional features; Salt

Tectonics. 2c. Understand the subsurface data (wells, seismic, geochemistry, etc) with outcrops

analogs. 2d. Characterisation of Source rocks, Reservoirs, and Seals. 2e. Characterisation of Traps and Structures. 2f. Hydrocarbon generation, migration and preservation processes. 2g. Ayoluengo Oilfield.



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


Discussion:

Characterisation 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, characterisation 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.



Itinerary:

Day 1. Carboniferous, Triassic and Jurassic of the Polientes Trough. Stops in Barruelo‐Brañosera: 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.


Field Trip Guide Gessal.

Petroleum System of the Basque Cantabrian Basin (South‐western Sector).



BOB 3 Well Logging

Lecturer

Mr. Jesús Sotomayor joined Repsol Exploracion in 1996, as a Senior Petrophysicist at the Department of Technology. He holds a Mechanical and Electrical Engineering Degree from the Instituto Tecnologico y de Estudios Superiores de Monterrey (ITESM). He worked several years for Schlumberger as a Wireline Engineer. In fact, in 1990 he joined Schlumberger Wireline Testing Data Services, as a Log Analyst; then, in 1993, he moved to Schlumberger GeoQuest as Computer Centre Manager and Senior Petrophysicist.

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.


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.

Programme

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.


Sonics.


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.


Microsoft Office.


“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.


BOB 4 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

Programme

1. Overview of Drilling.

2. Rig Components.

3. Bits.

4. Film: Rotary Rig.

5. Exercises:

5.1. Bit Selection and Grading. 5.2. Start Drilling program. 5.3. Start Equipment List/Rig Spec.

6. Drilling Fluids, Hydraulics.

7. Formation Pressures.

8. Casing Introduction.




9. Exercises:

9.1. LOT Evaluation.

10. Drilling Program:

10.1. Select Drilling Fluids. 10.2. Start Casing Design. 10.3. Start Logistics Program. 10.4. Casing Design (Cont.)

11. Cementing.

12. Well Control.

12.1. Film: Well Control.

13. Exercises:

13.1. LOT Evaluation. 13.2. Drilling Program. 13.3. Casing Design/Program. 13.4. Cementing Design.

14. Tutorials: Drilling Office.

15. Well Control.

16. Directional Drilling and Surveying.

16.1. Film: Directional Drilling.

17. Well Control, Directional Design, Survey.

18. Evaluation Exercises.


“Drilling Data Handbook”, Ed. Technip ‐ IFP. Halliburton Table.

“Field Data Handbook”. Dowell Schlumberger.

“IADC Drilling Manual”.

“Petroleo Moderno: Un manual basico 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.


BOB 5 Geophysics

Lecturer

Mr. Marcelo Benabentos joined Repsol in 2003, as a Geophysicist. He is the Manager of Geophysical Technologies based in Houston, Texas, USA. Before joining Repsol he worked for more than 20 years in Schlumberger in Seismic Acquisition, Seismic Data Processing and Reservoir Characterization. In his career he occupied the positions of Field Geophysicist, Data processing Supervisor, and Area Geophysicist. His expertise covers Seismic Design, Seismic Data Processing and Reservoir characterization. He currently works in Pore Pressure, AVO and Inversion projects. He holds a BSc. and a MSc. in Chemistry (University of La Plata, Argentina) and a MSc. in Geophysics (University of Houston, USA). He authored and co‐authored several papers on Survey Design, Reservoir Characterization, AVO and Seismic Inversion. He is an active member of SEG, EAGE, and IAPG.

Objectives

1. Become acquainted with the main geophysical methods used in exploration, their applications and their limitations.

1a. Be able to determine which geophysical methods are used and what for in the various phases of exploration.

1b. Be able to describe the gravity method, its possibilities and its limitations. 1c. Be able to describe the magnetic method, its possibilities and its limitations. 1d. Be able to describe the reflection seismic method, its possibilities and its limitations. 1e. Understand and be able to explain why the seismic method is the most successful one.

2. Understand the basic concepts of seismic wave propagation, reflection, diffraction and refraction.

2a. Understand and be able to describe what a seismic wave is and how it is generated. 2b. Understand and be able to describe how a seismic wave propagates through the earth. 2c. Understand and be able to describe the reflection process at a geological interface. 2d. Be able to distinguish the main wave types on a seismic record.

3. Understand in broad terms how 3D‐seismic land and marine data are acquired.

3a. Get to know what kinds of seismic sources are used in land and marine environments. 3b. Get to know what kinds of receivers are used in land and marine seismic data acquisition. 3c. Become acquainted with the most important acquisition parameters that influence the

quality and therefore the interpretability of seismic data. 3d. Get to know the approximate time needed for acquiring seismic data and the cost

involved.

4. Understand in broad terms how seismic data is processed.

4a. Become acquainted with the main processing steps applied to the data. 4b. Become acquainted with the most important processing parameters that influence the

quality and therefore the interpretability of seismic data. 4c. Learn how the lateral and vertical resolution can be improved and to what extent. 4d. Become aware of the main limitations of seismic processing. 4e. Get to know the approximate time needed for processing a seismic survey and the cost

involved.



5. Understand how seismic data can be linked to geology by using well data.

5a. Learn how the well‐shooting method is implemented. 5b. Learn how a sonic log is recorded and how it can be used. 5c. Learn how a density log is recorded and how it can be used. 5d. Learn how a synthetic seismogram is generated. 5e. Get to know the physical differences between a synthetic seismogram and a seismic

trace recorded at the surface. 5f. Get to know the major limitations and pitfalls in seismic calibration with well data.

6. Learn how seismic data can be converted from time to depth.

6a. Understand the main methods used for time‐to‐depth conversion. 6b. Become acquainted with the various sources for velocity information. 6c. Become aware of the accuracy and errors inherent in depth‐converted sections and

maps. 6d. Become aware of how depth conversion can change the structural image of a geological

horizon.

7. Get to know how 2D‐seismic data is interpreted and how horizon maps are made.

7a. Understand the principles of seismic interpretation. 7b. Understand the main objectives of seismic interpretation. 7c. Learn how to interpret a geologic horizon. 7d. Learn how to interpret faults and how to correlate those using seismic data and

geological reasoning. 7e. Understand the limitations of the 2D‐seismic method.

8. Learn how 3D‐seismic data is interpreted and how horizon maps are made.

8a. Understand the advantages of 3D‐seismic interpretation. 8b. Learn how to use time slices for seismic interpretation. 8c. Learn how to combine vertical sections and time slices to create accurate maps of

geological interfaces. 8d. Learn how 3D‐seismic enables faults to be interpreted much more accurately than 2D‐

seismic. 8e. Become acquainted with the principles of seismic attribute extraction. 8f. Understand how attributes can be used to predict reservoir quality and/or pore fill. 8g. Understand the limitations that are still present in the 3D‐seismic method. 8h. Understand how geophysical tools are used in exploration and production.

Syllabus

1. Introduction to Geophysics.

1.1. The Objective. 1.2. The Limitations. 1.3. Inversion of Data. 1.4. The Importance of Different Survey Methods. 1.5. The Gravity Method. 1.6. The Magnetic Method. 1.7. The Basic Seismic System. 1.8. The Seismic Objective. 1.9. The Role of Seismology in Hydrocarbon Exploration.

2. Seismic Waves.

2.1. Reflections. 2.2. Diffractions. 2.3. Refractions. 2.4. Ground‐Roll. 2.5. Multiples. 2.6. Reflection Coefficient.




3. Data Acquisition.

3.1. Seismic Sources. 3.2. Seismic Receivers. 3.3. Seismic Spreads. 3.4. Key Parameters in 3D‐Seismic Acquisition. 3.5. Logistics of Land Acquisition. 3.6. Logistics of Marine Acquisition. 3.7. Acquisition Time. 3.8. Acquisition Cost. 3.9. Video on Land and Marine Acquisition.

4. Data Processing

4.1. Processing Objective. 4.2. Main Processing Steps. 4.3. Interpretive Elements in Seismic Processing. 4.4. Processing Time. 4.5. Processing Cost.

5. The Link between Seismic and Well Information.

5.1. Overview Well Calibration. 5.2. Well Shooting. 5.3. Sonic and Density Logs. 5.4. Synthetic Seismograms. 5.5. Problems and Pitfalls in Seismic Calibration with Well Data. 5.6. Exercise on well calibration.

6. Time to Depth Conversion.

6.1. Overview Depth Conversion. 6.2. Velocity Information. 6.3. Depth Conversion Methods. 6.4. Limitations of the Various Methods. 6.5. Strong Lateral Velocity Variations. 6.6. Problems and Pitfalls in Depth Conversion. 6.7. Exercise on depth conversion.

7. 2D and 3D Seismic Interpretation

7.1. The Seismic Interpretation Objective. 7.2. Identification and Interpretation of Geologic Horizons. 7.3. How to Create a Horizon Map. 7.4. Fault Interpretation in 2D and 3D. 7.5. Problems and Limitations of 2D Seismic Interpretation. 7.6. 3D Seismic Interpretation. 7.7. Practical Interpretation Exercise of 2D and 3D Seismic.

8. Seismic Attributes.

8.1. The Meaning of Seismic Attributes. 8.2. Different type and use of Seismic Attributes. 8.3. Lithology and fluid Reservoir Analysis. 8.4. Shallow Hazards. 8.5. Pore Pressure Prediction. 8.6. Fractures and Anisotropy. 8.7. Cases Histories examples. 8.8. Exercise on AVO modelling.



Various simple exercises.

Video on Land and Marine Acquisition.

Well calibration.

Depth conversion.

Seismic Modelling.


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 1‐56080‐018‐6.

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.



BOB 6A Reservoir Geology and Characterisation

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.

Objectives

1. Become acquainted with the controls of deposition on the properties and geometries of reservoirs.

1a. Be able to describe the control of texture on poroperms. 1b. Be able to draw a block diagram of a meandering and braided fluvial reservoir. 1c. Be able to draw a block diagram of a shallow marine reservoir. 1d. Be able to draw a block diagram of a deep water reservoir.

2. Get to know how to recognize reservoir flow units.

2a. Be able to define flow units for range of layercake, jigsaw and labyrinth architectures. 2b. Be able to correlate a suite of logs in a layercake, jigsaw and labyrinth reservoir. 2c. Be able to correlate using a stratigraphic model.

3. Learn how to define the flow unit geometry in the subsurface.

3a. Be able to draw structural and stratigraphic cross‐sections. 3b. Get to know the difference between laterally continuous and discontinuous

lithologies/facies. 3c. Get to know the difference between log expression of a normal and reverse faults and be

able to interpret dipmeter data. 3d. Learn how dynamic data can be incorporated into flow units.

4. Learn how to draw maps of flow units.

4a. Understand the seal and cap rocks concepts. 4b. Be able to identify the differences and pitfalls between manual and computer methods. 4c. Be able to contour up a structural map and an isopach. 4d. Learn the difference between isopach and isochore. 4e. Understand the relationship between database and the quality of a map.

5. Learn how to define properties of flow units.

5a. Be able to define porosity/permeability and their typical pdfs. 5b. Be able to derive the flow regimes for arithmetic, geometric and harmonic averages. 5c. Understand the pitfalls of using averaging techniques. 5d. Understand the concept of spatial correlation and the relationship between a

semivariogram and geology. 5e. To be able to define core poro‐perm sampling programmes. 5f. Be able to relate core description to flow units.

6. Learn how to determine volumetric hydrocarbons in place.

6a. Become acquainted with the formulae for determining OOIP and GIIP. 6b. Learn how to determine volumes from maps. 6c. Be able to determine the net rock volume for a range of reservoir types. 6d. Get to know the difference between reservoir and surface volumes. 6e. Understand P10, P50, P90 and SPE reserves classification.



Syllabus

1. Sedimentology.

1.1. Texture and properties ‐ clastics. 1.2. Fluvial reservoirs ‐ geometries. 1.3. Shallow marine reservoirs ‐ geometries. 1.4. Deep water reservoirs ‐ geometries.

2. Correlation.

2.1. Introduction. 2.2. Stratigraphy. 2.3. Correlation panels and cross sections. 2.4. Stratigraphy and reservoir performance. 2.5. Architecture, drive mechanism and recovery. 2.6. Compartmentalisation and reserves. 2.7. 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.

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) Determination in Casablanca Field.

4. Geological statistics.

4.1. Introduction. 4.2. Measures of central tendency. 4.3. Measures of variability. 4.4. Distributions. 4.5. Sample sufficiency. 4.6. Measures of spatial correlation. 4.7. Tutorials.

a) Averages. b) Heterogeneity. c) Variograms.

5. Volumetrics.

5.1. Introduction. 5.2. Gross reservoir and Net Pay. 5.3. Deterministic HIP calculations. 5.4. Monte Carlo HIP calculations. 5.5. Reserves definitions and categories. 5.6. Handling Uncertainty.




5.7. Tutorials. a) Reserve determination exercises. b) Monte Carlo reserves ‐ Casablanca Field.

6. Reservoir Static Modelling.

7. Structural Framework.

8. Reservoir Correlation and Zonation.

9. Gridding Design.

10. Facies modelling / Petrophysical Property modelling.


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

Monte Carlo reserves ‐ Casablanca Field


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.


BOB 6B Reservoir Engineering

Lecturer

Mr. Emilio Carro was the Director of ISE's (now CSFR) MSc. in Oil and Gas Exploration and Production from 2003 until 2008. He is a Mining Engineer from ETSIM (UPM); Petroleum Engineer from ESPM (IFP); Master in Petroleum Engineering, H.K. Van Poolen; and MBA from IESE (UNAV). In the first thirteen years of his professional career (1970 to 1983) he held various technical positions with Repsol, in relation with drilling activities, reservoir and production engineering and production operations. Then he assumed managerial responsibilities, always connected to operations, first as Manager at Repsol's Tarragona Production Office, and then (1985 to 1993) as Company's Production Vice‐president. From 1993 to 2003 he served as General Manager of Repsol's Business Units in Egypt, UK and Libya.

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.

2a. Be able to calculate Pressure and Temperature Gradients for different Reservoir Fluids. 2b. Understand the concept of capillary pressure and its influence on Reservoir Fluid

Distribution. 2c. Learn how to estimate an HWC from a WFT Interpretation.

3. Understand the Phase Behaviour of Reservoir Fluids.

3a. Be able to classify the different reservoir fluids according to their initial condition (P, T) in a Phase Diagram.

3b. Understand the Relationship between Surface and Reservoir Volumes (PVT Parameters). 3c. Understand the Lab Experiments performed to calculate PVT Parameters. 3d. Understand a PVT Study Report. 3e. Learn how to use Fluid Correlations. 3f. Be able to calculate a Table with the corrected PVT parameters to be used for Reservoir

Engineering Studies (Material Balance or Simulation Models).

4. Understand Reservoir Production Mechanisms.

4a. Be able to identify different production mechanisms from Pressure‐Production Performance Plots.

4b. Get to know the range of Recovery Factors associated with those Mechanisms. 4c. Understand the differences between Gas and Oil Performances.

5. Become acquainted with the Material Balance Technique.

5a. Understand the theory of the General Material Balance Equation. 5b. Learn how to apply material balance for simultaneous OOIP and Aquifer determination. 5c. Learn how to use Material Balance for Prediction Performance. 5d. Become acquainted with the limitations of Material Balance and understand its

differences with Reservoir Simulation.

6. Understand Waterflooding.

6a. Understand the concepts of Relative Permeability, Mobility Ratio and Fractional Flow. 6b. Understand the Buckley Leverett Displacement Theory.



Syllabus

1. Reservoir Rock Properties.

1.1. Porosity. 1.2. Absolute Permeability (Darcy’s Law). 1.3. Saturations. 1.4. Capillary Pressure and Pore Size Distribution. 1.5. Wetability. 1.6. Effective and Relative Permeabilities.

2. Reservoir Pressure and Temperature.

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

3. Phase Behaviour of Reservoir Fluids.

3.1. Pure Substances. 3.2. Multicomponent Hydrocarbon Mixtures. 3.3. Pressure‐Temperature Phase Diagram Classification of Reservoirs. 3.4. 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. Radial Flow in a Porous Media. 4.2. Reservoir Drives and Production Mechanisms. 4.3. Primary, Secondary and Improved Oil Recovery. 4.4. Recovery Factors. 4.5. 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. Rock Relative Permeabilities. 6.2. Mobility Ratio. 6.3. Fractional Flow. 6.4. The Buckley Leverett One Dimensional Theory. 6.5. Oil Recovery Calculations (Welge Technique).


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.


“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.



BOB 6D Well Testing

Lecturer

Ms Elena Izaguirre is Head of Reservoir Engineering Technology in Repsol YPF. She received a Mining Engineering degree from ETSIM (UPM). She has been working for Repsol YPF VP Upstream since 1990 and has over fifteen 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

7. Become acquainted with Well Testing Data Acquisition and Interpretation Techniques.

7a. Understand the basic theory of well testing. 7b. Be able to design a well test. 7c. Get to know the tools needed to implement a well test. 7d. Understand a well test report. 7e. Be able to recognize different well‐reservoir models in a pressure derivative response. 7f. Understand the differences between oil and gas well testing. 7g. Be able to interpret a well test flow period in terms of reservoir properties and boundary

conditions using Pansystem.

Syllabus

1. Well Testing.

1.1. Fundamentals: a) Darcy’s Law and its Applications. b) Fluid and Pore Isothermal Compressibility. c) Radial Diffusivity Equation and its Solution for Monophase Fluid Flow in Porous

Media. d) Outer Boundary Conditions Transient (Infinite), Semi Steady State and Steady State. e) Superposition in Time and Space.

1.2. Well test Design and Execution: a) Objectives. b) Types of Tests. c) Downhole and Surface Equipment. d) Pressure Gauges and Rate Measurements. e) Sampling of Produced Fluids.

1.3. Basic well test Interpretation: a) Methodology. b) Techniques: Pressure Derivative, Type Curve Matching, and Specialized Plots. c) Early Time Near Wellbore Effects: WBS, Dimensionless Skin Factor. d) Radial Homogeneous Flow: Determination of Reservoir Parameters (k, S). e) Late Time Boundary and Depletion Effects:

‐ Single Fault. ‐ Intersecting Faults. ‐ Linear Flow (Channel Sands and Parallel Faults). ‐ Constant Pressure Boundaries. ‐ Closed Reservoirs.



f) Heterogeneous Reservoirs: ‐ Dual Porosity and Dual Permeability (Fissured and Layered Reservoirs). ‐ Radial Composite.

g) Multi‐phase Flow. h) Fractured Wells. i) Deviated and Horizontal Wells.

1.4. Gas Well Testing: a) Pseudo Pressure and Time. b) Non‐Darcy Flow. c) Deliverability Tests.

1.5. Practical Considerations: a) Productivity Index (PI). b) Well Inflow Performance Relationship (Use of PROSPER IPR Module).

2. Well Testing in Fractured Reservoirs.


Understanding a well test Report.

Interpretation of the pressure build‐up of an Undersaturated Oil.

Oil and Gas well test Interpretations exercises using Pansystem.


“Well Testing: Interpretation Methods“. G. Bourdarot, 1998. Editions Technip.

“Fractured Reservoirs”. A. Aguilera.



BOB 6E Reservoir Simulation

Lecturer

Dr. 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. Understand the role of numerical reservoir simulation in the context of reservoir economical development.

1a. Be able to describe reservoir simulation input data. 1b. Be able to describe reservoir simulation output data. 1c. Be able to describe the main steps to be taken in a reservoir simulation study.

2. Understand the fluid flow equations in a porous media.

2a. Become acquainted with the different terms involved in the conservation mass equation and Darcy’s law.

2b. Understand the differences between compositional and black‐oil model equations.

3. Understand the numerical discretisation of fluid flow equations.

3a. Understand the finite difference concept. 3b. Get to know the existence of different numerical schemes.

4. Grasp the general structure of an Eclipse Input Data File.

4a. Become acquainted with the main sections of an input data file. 4b. Understand the meaning of some main keywords.

5. Be able to use Eclipse 100.

5a. Be able to edit, modify an run an Eclipse input data file. 5b. Be able to analyse the results of a simulation run with different Post‐Processors.

Syllabus

Part I: Reservoir Simulation Overview.

1. Introduction to Reservoir Simulation.

1.1. Purpose and benefits of numerical reservoir simulation. 1.2. Relationship with other E&P matters. 1.3. Main steps in the construction of a Reservoir Simulation Model. 1.4. 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 Discretisation of the Fluid Flow Equations.

3.1. Notions about Finite Differences. 3.2. Types of Numerical Schemes:

‐ IMPES. ‐ Fully Implicit. ‐ 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.

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.

‐ Initialisation.

‐ Well description.

‐ History matching.

‐ Forecast simulations.


Eclipse 100.

Eclipse Office, Graf, Floviz.


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.; Prentice‐Hall. 1977.

Basic Applied Reservoir Simulation. Ertekin, T.; Abou‐Kassem, J.H.; King, J.R.; SPE Textbook Series N.3. 2001.



BOB 7A Subsurface Production Technology

Lecturer

Dr. David Davies joined Heriot‐Watt University, as Senior Lecturer in Production Technology, in 1996. He received BSc Hon in Chemistry, Upper Second and PhD degrees in Chemical Physics, in Experimental and Theoretical Thermodynamics, from Exeter University, England. He spent more than 25 years with Shell Group of Companies, including: Shell Chemicals UK; Shell International Exploration and Production Laboratory, Rijswijk, Holland; Brunei Shell Petroleum, Brunei, Borneo; etc.

Objectives

1. Introduction to Production Technology.

1a. Define the content and scope of Production Technology. 1b. Relate the production system and the well performance to the long term reservoir

dynamics. 1c. Discuss the integrated nature of production technology and its various technology

subsets. 1d. Understand the impact of production technology on the economics of capital investment

planning and operating cost budgeting. 1e. Discuss and define the concepts of well inflow performance and lift performance. 1f. Explain the interaction, in terms of well life cycle economics, between capital investment

and operating expenditure.

2. Well Completion Design.

2a. Evaluate and recommend bottom hole completion options based on well integrity and reservoir management requirements.

2b. Assess and recommend well designs for both production and injection wells. 2c. Identify, evaluate and recommend functional capability of completion strings for a

variety of situations. 2d. Describe the purpose and generic operating principles of major completion string

components. 2e. Identify well design limitations and potential operational problems. 2f. Assess well safety requirements and capabilities.

3. Perforating.

3a. Describe the options, their advantages and disadvantages for perforating oil and gas wells.

3b. Describe how to select between over‐balanced and under‐balanced perforating. 3c. Understand the importance of perforating charge design and what factors influence its

performance. 3d. Discuss the importance of protecting the perforations against formation damage during

completion and workover operations.

4. Well Outflow and Total System Performance.

4a. Explain the concept of systems analysis. 4b. List four segments in the production system where pressure losses occur. 4c. Define inflow performance curve, outflow performance curve and the solution node. 4d. Explain how systems analysis is used to estimate production rates. 4e. List the three components of pressure loss for fluid flow in pipes. 4f. Describe the fundamentals of Multiphase Flow. 4g. Estimate pressure drop in tubing using graphical techniques. 4h. Identify the purpose of a choke. 4i. Define critical and subcritical flow.




5. Artificial Lift Review.

5a. Explain the importance of Artificial Lift (AL) for world oil production. 5b. List the different types of AL and explain their operating principle. 5c. Discuss AL selection criteria.

6. Formation Damage.

6a. Understand the importance of the near wellbore area in terms of formation damage and poor well performance.

6b. Calculate the cost of formation damage. 6c. Identify the major sources of formation damage e.g. during drilling and completion

formation, production etc. as well as the appropriate remedial actions. 6d. Provide guidelines for minimising formation damage during workover operations. 6e. Indicate how the presence of formation damage can be identified in a production or

injection well.

7. Acidising and other Matrix Stimulation Techniques.

7a. Describe the role of and mechanism by which matrix stimulation improves well production performance.

7b. Describe the well stimulation design methodology. 7c. Identify well stimulation candidates. 7d. Discuss the importance of the stimulation cycle. 7e. Prepare a treatment design i.e. select the acid formulation, acid volume and acid pump

rate.

8. Subsurface and Surface Operations.

8a. Discuss the properties of Oil and emulsions. 8b. Describe operational problems associated with Water Production. 8c. 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. Shaped charge design and performance. 2.2. Perforation Pattern and Well Inflow Performance. 2.3. Perforation Charge Performance. 2.4. Perforation Gun Types. 2.5. Perforating Techniques. 2.6. 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.


4. Introduction to Artificial Lift.

4.1. The need for Artificial Lift. 4.2. Types of Artificial Lift. 4.3. Selection of Artificial Lift. 4.4. 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. Acidising & other Matrix Stimulation Techniques.

6.1. Well Inflow and its improvement by Well Stimulation. 6.2. An Introduction To Well Stimulation Economics. 6.3. Candidate Selection. 6.4. Matrix Stimulation Fluid Section. 6.5. 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. Emulsions. 7.2. Scale Formation. 7.3. Produced Water Management. 7.4. Hydrates Formation. 7.5. Pigging.


“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 Optimisation 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.



BOB 7B Surface Production Technology

Lecturer

Mr. Gomis has over 15 years experience as a process engineer. MSc Oil Refining, Gas, and Petrochemistry (UNIMET, 1994). BEICIP‐FRANLAB (IFP subsidiary) Diploma, Postgraduate Cycle in Oil Refining, Gas and Petrochemistry. Mechanical Engineering (USB, 1990). Repsol YPF: Head of Production & Facilities Engineering EAA. 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.

Objective

Understand the basic principles behind the Oil & Gas processing Facilities and Specifications.

Syllabus

1. Introduction: Oil & Gas Production, Gas Processing, Facilities Overview.

2. Basic Principles: Physical Properties, Equation of State, Phase Behaviour, Vapour‐Liquid Equilibrium.

3. Water‐HC Systems: Water Content Correlations, Hydrate Prediction, and Hydrate Inhibition.

4. Calculation of Energy Requirements: Thermodynamics Concepts, Energy Balances.

5. Flow Systems: Liquid, Gas, Two Phases.

6. Separation Equipments: Flow Stations, Crude Oil Stabilization, Production Separators, Wash Tanks, Crude Oil Treating, Desalting. Heat Transfer Equipments: Heat Exchangers, Furnaces, Air Coolers.

7. Pumps & Compressors: Reciprocating, Centrifugals, and Drivers.

8. Refrigeration Systems: Vapour Compression Systems, Expansion, Turbo Expansion.

9. Gas Dehydration: Glycol, Adsorption Systems.

10. Gas Sweetening: Amine, Membranes.


ESI/PEF.

Hysys.




“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.



BOB 8 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 economical 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. Understand the main targets of the E&P companies.

1a. Get to know the phases of an E&P project. 1b. Be able to allocate a technical risk to each phase of an E&P project. 1c. Get to know the ways of land acquisition. 1d. Understand the impact of operating environment in a project's economics.

2. Become acquainted with the main management indicators in a E&P company.

2a. Understand the concept of “finding cost” and have an idea of its current range of values. 2b. Grasp the meaning and understand the importance of “reserve replacement”. 2c. Understand the meaning of “write‐off rate”. 2d. Understand why E&P is a capital‐intensive industry. Become acquainted with the

commitment made by the sector to maintain investments through the reinvestment ratio.

2e. Get to know the weight of E&P in a integrated oil company. 2f. 2f. Become acquainted with the profitability corresponding to different geographical

areas.

3. Be acquainted with E&P contract features.

3a. Be aware of the impact that a royalty “in kind” has on booked reserves. 3b. Understand why royalties are regressive. 3c. Understand the economic impact of minimum work program and financial

commitments. 3d. Become acquainted with the basic elements of a PSC contract. 3e. Understand the importance of a “Cost‐oil limit”. 3f. Understand the consequences of “ring fencing”. 3g. Get to know the meaning of “net reserves” in a PSC contract. 3h. Become acquainted with the different ways of Government take. 3i. Get to know some incentives in a PSC schemes. 3j. Identify the key features of a service contract. 3k. Identify the key features of a concession contract. 3l. Get acquainted with the most important common issues in all contract types: areal

extent, term, relinquishments, sole risk, force major, working and carried interest, etc.



4. Get to know and understand the fundamentals of decision analysis.

4a. Understand the differences between uncertainty and risk. 4b. Understand the Expected Value concept. 4c. Understand the interpretation of Expected Value. Average Profit per Decision. The Law

of Large Numbers. 4d. Learn how to build decision trees. 4e. Learn how to solve decision trees. 4f. Learn how to calculate the maximum tolerable risk in a exploration prospect. 4g. Become acquainted with statistical concepts: sample, event, definitions of probability,

independent and equally likely events, conditional probability, probability distributions, etc.

4h. Understand that “decision makers” are not impartial to money.

5. Learn how to perform an economic evaluation of an E&P project.

5a. Learn how to use an economic model. 5b. Learn how to calculate the economic indicators. 5c. Learn to define the key variables, and the strengths and weaknesses of a project. 5d. Learn how to find prices and interest rate references. 5e. Be able to inform about the main economic results.

6. Become acquainted with the E&P accounting standards.

6a. Get to know the importance of a “ceiling test”. 6b. Become acquainted with the successful effort depreciation method. 6c. Become acquainted with the full cost depreciation method. 6d. Become acquainted with the unit‐of‐production depreciation method.

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 and abandonment. 1.3. Ways of land acquisition. Up‐front payments. Farm in‐out economic consequences. 1.4. Areal extent. “Ground floor”. 1.5. Working obligations. Mandatory and discretionary programs. 1.6. 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. E&P main indicators. Investor benchmarking. 2.2. Reserve replacement. Ways to replace reserves. Reserve life. 2.3. Finding cost. Full cycle cost. Trends. 2.4. Exploration performance. Write‐off rate. Trends. 2.5. Reinvestment ratio. Trends. 2.6. E&P expenditures per production unit. Trends. 2.7. E&P current cost escalation. 2.8. E&P is still the most important business in oil‐gas industry. 2.9. E&P profitability by geographic area.



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. Service contract. With or without risk. 3.4. Association contract. 3.5. New contracts: "k factor" (Algeria), “Buy‐back” (Iran). 3.6. 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.

4.1. Objectives of an economic evaluation. 4.2. “Economics” in the E&P asset lifecycle: purpose, key variables, and risks. 4.3. Phases of a project's economics. Evaluation network. 4.4. Measures of profitability. Characteristics. 4.5. Economic evaluation. Full cycle and half cycle. 4.6. Discounted net cash flow method. Building the cash flow. 4.7. 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.

5. Decision analysis.

5.1. Concepts: uncertainty, exposure to uncertainty, risk, etc. 5.2. Basics of probability and statistics concepts. 5.3. The “shape” of oil patches uncertainty. 5.4. Expected value concept. Meaning and interpretation. 5.5. Decision trees. Chance node. Decision node. 5.6. Solving a decision tree. 5.7. Maximum tolerable dry hole risk. 5.8. Preference theory concepts.

6. Accounting and Financial Statements.

6.1. “SFAS 69”. SEC Standards for booking reserves. 6.2. “Ceiling test” and Year Closing. 6.3. Booking reserves. 6.4. Full Cost and Successful Effort methods. 6.5. The unit‐of‐production depreciation method. 6.6. Final summary.

7. Miscellaneous.

7.1. Oil market. Prices. Why are prices so difficult to forecast? 7.2. Gas Market has a regional structure. Prices. 7.3. Oil vs. Natural Gas. Different risks. 7.4. Gas market. Net‐back and build‐up prices. Examples. 7.5. Final summary.




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.


“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.



BOB 9 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.

Objectives

General: To understand and learn how to cope with risks and uncertainties related to E&P activities. This module is aimed to:

1. Identify risks and uncertainties intrinsic to the Exploration and Production.

2. Understand the basic statistical measures and probability distributions.

3. Be able to assign Exploration Prospect Risk.

4. Learn how to estimate Prospect/Field probability distribution of sizes.

5. Learn how to deal with risk and construct decision trees analysis.

6. Understand methods for risk diversification and Portfolio Management.

7. 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. Sorting data. Creating frequency distributions 2.2. Discrete or continuous distribution of values 2.3. Measures of central tendency. 2.4. Normal distributions and Lognormal distributions.

3. Dealing with Risk. Improving Estimates. Defining Exploration Risk.

3.1. Discriminating Facts from Opinions. Subjective Probability. 3.2. How to improve estimates. The value of data and knowledge. 3.3. Defining Geological/Technical Risk Variables. 3.4. 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 (novice level!): 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.




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.


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


Microsoft Office.


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.

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.


BOB 10 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.

1a. The transition from shore. 1b. The first offshore platform. 1c. The environmental conditions. 1d. The seakeeping. 1e. The station keeping.

2. The fixed production units.

2a. Jackets. 2b. Gravity Platforms. 2c. Jack‐ups.

3. Objective 3: Mobile Offshore Drilling Units.

3a. Floating drilling. 3b. Submersible. 3c. Jack‐up. 3d. Semisubmersible. 3e. Drillship and barges.

4. Floating Production.

4a. Well testing and early production. 4b. Semisubs. 4c. F.P.S.O. 4d. Spar and other deep draft solution.

5. The Hybrid solution.

5a. The TLP.

6. The subsea production.

6a. The subsea wellheads. 6b. The templates. 6c. The flowlines.

7. Export.

7a. The storage. 7b. The pipeline.

8. Support fleet.

8a. Exploration. 8b. Installation. 8c. Operation. 8d. Abandoning.

9. Planning and costing.

9a. Production units.




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. Considerations for Design. 2.2. Jacket, piling, MSF and topsides. 2.3. The installation. 2.4. Drilling. 2.5. Production.

3. MODU ‐ Mobile Offshore Drilling Units.

3.1. Considerations for Design. 3.2. The drilling riser. 3.3. The motion compensation. 3.4. The mooring system. 3.5. 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.


IMO MODU CODE.

Harris Deepwater Floating Drilling Operations.

Petroleum Publishing Company.

ETA Offshore Seminars.

Developments in offshore engineering.

GPC Herbich.


Timetable

Week Date Group A Group B Hours

0 Sep 1 ‐ 3 Refreshment courses: Geology for Engineers and Mathematics and Physics for Geologists

Refreshment courses: Geology for Engineers and Mathematics and Physics for Geologists

1 Sep 6 ‐ 10 Introducción General a RYPF y a la Industria

Introducción General a RYPF y a la Industria

2 Sep 13 ‐ 17 BOB 1A/C Basic Petroleum Geology and Structural Geology

BOB 1B Basin Analysis and Petroleum Systems

37.5

3 Sep 20 ‐ 24 BOB 1B Basin Analysis and Petroleum Systems

BOB 1A/C Basic Petroleum Geology and Structural Geology

37.5

4 Sep 27 ‐ Oct 1 BOB 5 Geophysics BOB 5 Geophysics 37.5

5 Oct 4 ‐ 8 BOB 4 Drilling Engineering BOB 4 Drilling Engineering 37.5

6 Oct 11 ‐ 15 BOB 6A Reservoir Geology and Characterisation

BOB 6A Reservoir Geology and Characterisation

30.0

7 Oct 18 ‐ 22 BOB 3 Well Logging BOB 2 Geology Field School 37.5

8 Oct 25 ‐ 29 BOB 6B Reservoir Engineering BOB 3 Well Logging 37.5

Nov 2 BOB 10 Offshore Structures Seminar 9

Nov 3 ‐ 5

BOB 6D Well Testing

BOB 9 Risk Analysis

30.0

10 Nov 8 ‐ 12 BOB 6E Reservoir Simulation BOB 8 Economic Evaluation 30.0

11 Nov 15 ‐ 19 BOB 7A Subsurface Production Technology

BOB 7A Subsurface Production Technology

37.5

12 Nov 22 ‐ 26 BOB 7B Surface Production Technology BOB 6B Reservoir Engineering 37.5

Nov 29 ‐ 30 BOB 10 Offshore Structures Seminar 15 13

Dec 1 ‐3 BOB 9 Risk Analysis

BOB 6D Well Testing

22.5

14 Dec 6 ‐ 10 BOB 2 Geology Field School 37.5

Dec 13

BOB 6E Reservoir Simulation

15

Dec 14 ‐ 17

BOB 8 Economic Evaluation

BOB 7B Surface Production Technology

37.5

Total Lecture Hours 502.5



SPECIALISATION BLOCK Edinburgh. January ‐ March 2010

SPECIALISATION BLOCK

General Information about the School

The Institute of Petroleum Engineering is a specialised centre in teaching, training and research with the largest PE research programme 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. The student from CSFR after completion of the Basic Overview Block in Madrid, 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.



Specialisation in Petroleum Engineering

Course Overview

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 Engineering Well Testing S Zheng

The overall aim of this module is to:

Understand the diffusivity equation and the derivation of analytical solutions related to reservoir features (wells, fractures, aquifers).

Use the analytical solutions to describe fluid flow in a reservoir.

Calculate reservoir permeability in simple and complex reservoir geometries.

Reservoir Simulation K Sorbie


Develop an understanding of the role of simulation in reservoir engineering.

To gain insight into the value of simulation.

To provide the appropriate numerical techniques to enhance hydrocarbon recovery.

Petroleum Economics J Fennema


Understand the economics concepts involved in project evaluation.

Understand the value of investments as defined within a fiscal system.

Evaluate risks associated with economic decisions.

Production Technology D Davies


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.

Design appropriate procedures to ensure optimal initial production.

Understand the process of delivering and treating reservoir and injection fluid at the surface.



Specialisation in Reservoir Evaluation and Management

Course Overview

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.

Well Testing and Production Logging S Zheng


Understand the diffusivity equation and the derivation of analytical solutions related to reservoir features (wells, fractures, aquifers).

Use the analytical solutions to describe fluid flow in a reservoir.

Calculate reservoir permeability in simple and complex reservoir geometries.

Reservoir Simulation K Sorbie


Develop an understanding of the role of simulation in reservoir engineering.

To gain insight into the value of simulation.

To provide the appropriate numerical techniques to enhance hydrocarbon recovery.

Rock Mechanics, Geomechanics and Geophysics J Sommerville


Understand the lab measurements of rock properties under stress.

Describe and represent the geometric characteristics of reservoirs. Explain development of reservoir shape in terms of deformation processes.

Understand the principles of core measurements, including sampling strategy, SCAL and the derivation of a, m and n.

Understand Pc and Saturation relationships and relative permeability measurement.

Understand the difference between imbibition and drainage curves and their measurement and interpretation.

Understand the need for corrections of petrophysical core measurements and the relation of core



measurements to logs.

Understand impact of deformation on fluid flow, specially the role of faults and fractures.

Geomechanical approach to understanding flow in deformed rocks.

Reservoir geophysics (basic principles). Influence of rocks and reservoir fluids on seismic properties.

Seismic attributes and seismic inversion.

Imaging and resolution (tuning effects).

Correlation between reservoir characteristics and attributes.

Acquisition and processing (fundamentals, migration).

4D Seismic.

Modelling and Management P Corbett


Understand the concept and basis of geomodelling (includes geostatistics and equiprobable realisations).

Understand the workflow in constructing a geomodel.

Understand the role of integration in geomodelling.

Understand reservoir management.

Understand uncertainty in geomodelling and how is treated.




Specialisation in Geoscience for Subsurface Exploration, Appraisal and Development

Course Overview

From this course, two different specialisations arise, one for Petroleum Geology and the second for Petroleum Geophysics. 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 as explained below:

Reservoir Geophysics & Sedimentary Basins C MacBeth A Gardiner G Couples

The overall aim of this module is to understand:

Reservoir Geophysics (basic principles). Influence of rocks and reservoir fluids on seismic properties.





4D Seismic.

And develop basic understanding of gravity and magnetic surveys.

Petroleum Basins 1 R Wood


Understand the physical characteristics of a petroleum basin.

Petroleum Basins 2 J Sommerville



Describe and represent the geometric characteristics of reservoirs. Explain development of reservoir shape in terms of deformation processes.

Understand the principles of core measurements, including sampling strategy, SCAL and the derivation of a, m and n.

Understand Pc and Saturation relationships and relative permeability measurement.

Understand the difference between imbibition and drainage curves and their measurement and interpretation.

Understand the need for corrections of petrophysical core measurements and the relation of core


measurements to logs.

Understand impact of deformation on fluid flow, specially the role of faults and fractures.


Reservoir geophysics (basic principles). Influence of rocks and reservoir fluids on seismic properties.





4D Seismic.

Timelapse, Multicomponent & Exploration Seismic C MacBeth ** For Geophysicists


Understand the use of timelapse seismic.

Understand the origin and use of seismic anisotropy.

Diagenesis, Geomodelling and Geomechanics G Couples ** For Geologists




Understand the concept and basis of geomodelling (includes geostatistics and equiprobable realisations).

Understand the workflow in constructing a geomodel.

Know the drivers for diagenesis and the petrophysical consequences, particularly for clastic rocks.




Guidance on Assessment

Lecturers will discuss the format of their specific examinations. Examples of examinations questions and answers will be provided at a time considered appropriate by the lecturer.

Some modules may include assessed tutorials, for which reports are to be delivered and attendance may assessed as well. The infrastructure of the IPE allows proper delivery of reports on duty and the weight on the final mark is discretional to the lecturer.

Final exams are taken in Madrid, preceded by a study period in CSFR. External examiners approved by Heriot‐Watt University supervise that all assessment regulations are complied as if the exams were taken in Edinburgh.


FIELD TRAINING BLOCK Spain. December 2010 Argentina. April 2011


Drilling Field School

Collaborators

SENDA Team

Objectives

Observe the technology used in a drilling rig, drill string, bits, and hoisting system. Show the mud system, pits, screen shakers, and solids control equipment. Identify the different components involved in the BOP stack. Analyze the drilling control room and alarm systems.

Itinerary

Introduction to drilling safety considerations. Visit drill string inspection supplier. Observe and understand the run‐in‐hole and pool‐out‐of‐hole manoeuvres. Describe the roles of the tool pusher, rough necks, company man and derrick

man. Look at the mud system components. Observe a calliper running. Understand a cementing operation. Visit a coring company. Observe the different measurements taken and its interpretation.

Production Field School

Objectives

Observe field operations, equipment spud, pulling and work over. Evaluate the needs for roads to the site, well site dimensions, wellheads and

production equipment. Recognize the instrumentation and monitoring systems in the field (scada). Visit the field facilities; identify the different treatment units and the installations

used for secondary recovery. Analyze the different roles of the personnel involved in field work. Observe a LACT unit; analyze the drilling control room and alarm systems.

Itinerary

General description of production facilities. Dehydration plant, oil treatment and water injection facilities. Loading site visit, tanks, LACT unit, and operations description. Laboratory measurements. ESP’s, PCP’s and rod sucker pump production mechanisms observation. Pulling and work over unit.



TEAM PROJECT BLOCK Madrid. May ‐ June 2011

TEAM PROJECT BLOCK

Overview

Objective

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 a hydrocarbon field, and will establish, based on the information provided, a geologic 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.

Brief description of the case

The data will be taken from 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.

Students should reach conclusions that are not far away from reality in terms of Recoverable Reserves.

Overall characteristics

The project lasts 3 months. Students should familiarise themselves with the data, some of which might be in

Spanish; analyse it and reach conclusions regarding the petroleum model and main parameters of the field; perform interpretations, establish drilling and development programs, design installations, make economic evaluations, propose alternatives, etc, and make a final presentation.

The database will be composed of information in magnetic support format (basically 3D Seismic and wells) and printed material, correctly classified and accessible. Since some of the data might be over 20 years old, the students should not minimise learning the applicability of old techniques and tools. They could be faced with a similar situation in their professional life.

Specialised computer technicians from Repsol will assist students with the use of an industrial software package.

Among Repsol personnel, a group of specialists will be appointed, in charge of solving specific questions. A schedule will be established for consults and visits to CSFR by these specialists.

Students will be organised into multidisciplinary teams. 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.

The following is a list of the most important courses taught and tutorials assessed during the Specialisation Block.


TEAM PROJECT BLOCK

Competencies Module

Lecturer

Conorg

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.

Contents:

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.


TEAM PROJECT BLOCK

Geoframe (Charisma)

Lecturer

Mr. David Sorrentino graduated in Bachelor Geological Science in Universidad Nacional de La Plata, Buenos Aires, Argentina in 1994. He has also accomplished a Postgraduate Program in Mapping and Interpretation delivered by YPF, S.A. (1996). Starting as a Mud Logging engineer in the San Jorge Basin, Argentina for Baker Hughes, he continued his development in Schlumberger for more than 10 years in the SIS (Information Technology Department). In April 2008 he joined Repsol Upstream E&P Department as a Senior Geologist, specialized in Seismic Interpretation and Geomodelling within the Geoscience Technical support Team.

Objective

Familiarise with Geoframe and use Charisma as an Interpretation tool.

Syllabus

Geoframe Geomodel and workflow.

QC of seismic data before seismic interpretation.

Interpretation Model in Geoframe 4.

Visualisation and Selection of seismic data.

Boreholes and log curves in IMain.

Horizon interpretation.

ASAP and Loop Autotrack.

Fault interpretation.

2D Interpretation using grids.

Mapping and gridding tools in Charisma IMain.

Use of Grid Manager Tools (Grid Operations).

Seismic Attribute calculation.

Use of 3D visualisation tools (GeoViz and GeoCube).

Main tools in GeoViz to visualize interpretation results.

Main workflow of Voxel Pick (Discussion).

Workflow to interpretation of project data.


Paisley Project.


Charisma Training Manual.


TEAM PROJECT BLOCK

CPS3

Lecturer

David Sorrentino.

Objective

Introduce CPS3 as a mapping tool.

Syllabus

Introduction to CPS3.

CPS3 in the Geoframe 4 Workflow.

CPS3 Modules.

CPS3 Set Types and CPS‐3 Partitions (DSL).

Integration of CPS3 in Geoframe 4.

Selection, Creation and Management of CPS3 Sets.

Introduction to Display and Modelling Environments.

Main CPS3 Workflow.

Gridding Fundamentals.

Gridding Algorithms in CPS3.

How to Choose a Gridding Algorithm.

Convergent Gridding.

Grid Contouring.

Fault Surface Operations.

Model Editor.

Surface Operations.

Computing of Volumetric Envelope.

Oil in Place.

Geoframe Basemap (discussion).


Paisley Project.


CPS3 Training Manual. AAPG Papers.


TEAM PROJECT BLOCK

Petrophysical Applications

Lecturer

Jesus Sotomayor. Please refer to Basic Overview section.

Objective

Use Petroview to analyse logs. Establish Well correlations with software.

Syllabus

Petroview ‐ Petrophysical Evaluation. WellPix ‐ Zoning Reservoir Layers. ResSum ‐ Summing and Averaging Reservoir Properties. MultiWell PetroView ‐ Petrophysical Evaluation. Carbonates PetroView ‐ Petrophysical Evaluation.

Software applications

PetroView. WellPix. ResSum.


“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.


TEAM PROJECT BLOCK

MBAL ‐ PROSPER ‐ GAP

Lecturer

Petroleum Experts is a petroleum engineering company that develops a set of engineering software tools. Petroleum Experts currently has more than 195 client companies in 60 countries worldwide. All the major international oil companies have taken the IPM suite as their corporate standard. Petroleum Experts was created in 1995 by a team of professional engineers and programmers. All members of the team have been involved in the development of software engineering products, as well as having extensive experience in petroleum engineering.

Objective

The course is designed to improve the engineers understanding of the approach to building Integrated Production Models. There is a focus on the engineering, quality control and program navigation.

Syllabus

Introduction to Integrated Production System and why an overall approach is necessary.

Introduction to Prosper.

Pressure loss in the wellbore.

Importance of PVT.

VLP flow correlations theory.

Inflow Performance Model Vogel, Darcy, Multilayer, Horizontal, fractured.

Introduction to MBAL.

Aquifer Models, history matching techniques.

Introduction to GAP.

Building a surface network model.

Pipeline Modeling and Matching.

Adding constrains at well, manifold, pipeline and separator level.


Petroleum Experts Software Manuals and guidelines.


TEAM PROJECT BLOCK

Hysys

Lecturer

Jose Enrique Gomis. Refer to Basic Overview Block section.

Objective

Understand the basic principles of Surface Facilities Simulation and use Hysys to model the project Facilities.

Syllabus

Fluid Characterisation: single component systems, mixtures, and gas chromatography, ASTM, TBP.

Equation of state and Their Application: PVT relationships, logic diagrams, comparison calculations.

Calculation of thermodynamic properties: physical properties, phase behaviour, vapour‐liquid equilibrium.

Characterisation of C6+: SpGr, PM, Tb, Chromatographic analysis, partial TBP, parameters of EOS.

Hydrocarbon ‐Water Behaviour: Water content, gas saturation, hydrate formation, and inhibit hydrate formation.

Separation systems: Flash Calculations, 2&3 phase separators. Gas compression: Isentropic process, Power calculation, compression ratio per

stages, effect of gas composition, effect of cooling temperature, NGL Recovery: constant enthalpy expansion, isentropic expansion, basic

calculations, C6+ characterisation effects, CO2 freeze up Multicomponent distillation: specifying multicomponent separation, crude oil stabilisation.

Fluid Flow: incompressible flow, compressible flow, two‐phase flow.

Software applications

Hysys


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. PenWell Books, Tulsa Oklahoma. ISBN 0‐87814‐342


TEAM PROJECT BLOCK

Questor Offshore

Lecturer

Jose Enrique Gomis. Please refer to Basic Overview Block section.

Objective

Learn how to obtain project Investments and costs through Questor.

Syllabus

Project Phases.

Cost Estimation Concepts. Level of cost Estimates. Contingency. Questor modules Definition.

Project Properties. Field Level Data.

Production Profiles. Selecting Field Development Concepts.

Component Level Data.

Operating costs.

Scheduling.

Investment and Production Profiles.


Gas conditioning & Processing Volume I, II, III. JMC Campbell. Campbell Petroleum Series, Norman, Oklahoma. Library of Congress Catalog Card 76‐15

PVT and Phase Behavior 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 & Thompsom R. PenWell Books, Tulsa Oklahoma. ISBN 0‐87814‐342.


TEAM PROJECT BLOCK

Team Project Timetable

Date Lecturer Compulsory Consultancy and Courses

4 / 8 Conorg All/38 Soft Skills (Competencies)

11 / 16 J. Sparrowe All/38 Health, Safety & Environment

18 / 29 SENDA Team All/38 Drilling & Production Field Trip

2 Suarez ‐ Chirinos All/38 Project Kick Off

5 E. Matheu GG‐GPH‐REM (21) Carbonate Systems

APRIL

6 E. Matheu GG‐GPH‐REM (21) Field Trip Geology

9 / 13 D. Sorrentino 2 per group (16)

GG‐GPH Mandatory Seismic Interpretation (Charisma)

9 / 17 R. Carden PE‐DRLL (17) Drilling Practices (Petroskills)

16 ‐ 17 A. Arrieta 2 per group (16)

GG‐GPH Mandatory Synthetics

18 / 20 J. Underhill GG‐GPH (12) Seismic & Sequence Stratigraphy

18 ‐ 19 K. Mohamed REM‐PE (26) Oilfield Manager (OFM)

21 E. Izaguirre REM (9) Reservoir Evaluation Data Room

23 ‐ 24 E. Gomis Compulsory PE (16) Facilities Simulation (Hysys)

25 Suarez ‐ Chirinos All (38) Phase I Meeting

26‐27‐28 J. Sotomayor 2 per group (16)

GG‐REM Petrophysical Applications

28 M. Fernandez PE‐DRLL (17) GIP : Drilling Planning

May 30 / Jun 3 Petex 2 per group (16)

REM‐PE MBAL ‐ Prosper ‐ GAP

MAY

May 30 / Jun 3 S. Quesada GPH‐GG (12) Petroleum Systems & Basin Analysis

(BasinMod)

6 / 8 R. Ramones DRLL (8) Landmark Software

6 / 9 D. Sorrentino 2 per group (12)

GPH‐GG CPS 3 Mapping & Gridding

10 A. Arrieta 2 per group (16) GPH Mandatory

Time to Depth conversion

13 J. Sotomayor GG‐REM (17) Petroview Plus

13 ‐ 14 M. Moreau PE‐DRLL (17) Offshore Installations

14 / 16 J. Garcia‐Fanjul GG‐REM (17) Reservoir static modelling (Petrel)

17 Suarez ‐ Chirinos By Group Phase II meeting

20 ‐ 21 F. Mustieles REM (9) Reservoir Simulation (Eclipse 100)

22 J. Gomis PE (17) Hysys

23 J. Gomis PE (17) Questor Offshore

JUNE

27 ‐ 28 G. Gonzalez 2 per group (16) Economic Evaluation

4 ‐ 5 Board All Project Dissertation

JULY

8 ‐‐ All Closing Ceremony. Graduation


gas exploration and production

Documents