Action Learning Modules

Define the properties of the reservoir rock/fluid system.

Upon completing this Learning Module assignment, the participant should be able to

• define the following reservoir properties and understand their importance in the overall reservoir development scheme:
• Rock properties: porosity, permeability, fluid saturation, compressibility, anisotropy
• Fluid properties: phase behavior, PVT relationships, density, viscosity, compressibility, formation volume factor, gas-oil ratio
• Rock/fluid interactions: wettability, interfacial tension, capillary pressure, relative permeability
• read and understand wellsite descriptions of recovered core material, evaluate the core handling and preservation techniques employed, and select sample intervals for laboratory analysis
• generate a procedure for preparing and analyzing selected core samples, specifying the tests to be run and the information to be obtained; describe the laboratory techniques and perform the calculations used for determining rock properties
• design procedures for obtaining representative surface and subsurface formation fluid samples
• describe procedures for generating PVT analyses of reservoir fluid samples, and interpret the resulting reports
• use published correlations to estimate reservoir fluid properties

In this assignment, you will define the basic rock and fluid properties of a recently discovered reservoir in the Republic of Sucre.

You will be in charge of obtaining representative fluid samples and determining their Pressure-Volume-Temperature (PVT) characteristics. You will also design a coring and core analysis program for a new well, and use the results to define basic rock properties and rock-fluid interactions.

The discovery well, Well 4E1-NE, tested at 1550 STB/D of 35 degree API oil [246 m³/D, 0.85 specific gravity], with a producing gas-oil ratio of 680 SCF/STB [121 m³/m³] and a water cut of about three percent. It is currently on an extended production test.

The second well drilled in this field , Well 5C1-SW, tested all water and was subsequently suspended.

Before your company acquired these drilling blocks, a medium-sized independent had run a series of seismic surveys in the area. Your company purchased these data, from which the Geology and Geophysics departments constructed a subsurface contour map showing the approximate structure boundaries and the top of the Upper Sand.

You are now part of the interdisciplinary team charged with characterizing the reservoir and developing an optimal exploitation strategy. Right now, you do not have much to work with—just the contour map and the well data obtained so far. (You can access this material by clicking on the References that accompany each assignment question.)

What you will need to do at this point, then, is to use the available data to try to define some basic reservoir rock and fluid properties.

In order to successfully complete this assignment, you will need to complete the following Background Learning subtopics, or be familiar with the subject matter that they contain:

Fundamentals of Reservoir Engineering

• Basic Concepts in Reservoir Engineering

Coring and Core Analysis

• Borehole Environment
• Bottomhole Coring (Coring While Drilling)
• Sidewall Coring (Coring After Drilling)
• Major Types of Core Analysis
• Core Sample Preparation
• Porosity Measurement
• Permeability Measurement
• Saturation Measurement
• Complementary Core Information
• Core Analysis Reports
• Special Core Analysis

Fluid Sampling and Analysis

• Hydrocarbon Phase Behavior
• Hydrocarbon Gases
• Hydrocarbon Liquids
• Two-Phase Systems
• Formation Water
• Fluid Sampling: General Considerations
• Hydrocarbon Sampling
• Water Sampling
• Sampling: Transportation and Safety
• Reservoir Fluid Analysis
• Reservoir Fluid Correlations

Apply rock mechanics fundamentals to discribe well, reservoir and production behavior.

Upon completing this Learning Module assignment, the participant should be able to

• define the following rock mechanical properties under various conditions of confining pressure, describe how these properties influence wellbore stability, directional drilling considerations, well completion design and other aspects of reservoir development, and know how they are measured in the laboratory:
• Brinell hardness
• Tensile strength
• Normal/shear stress relationships and failure mechanisms (Mohr circles)
• Young’s modulus
• Poisson’s ratio
• Compressive strength
• Shear strength

Rock mechanics is a basic element of reservoir description, well design and production optimization. Knowledge of rock mechanical properties is critical to successful reservoir management.

In this assignment, you will define rock mechanical properties based on an analysis of core samples from Well 2A5-NE. You will:

	(1)	select core samples for measuring rock mechanical properties
	(2)	estimate the overburden and pore pressuress at reservoir depth
	(3)	determine rock mechanical properties under reservoir conditions
	(4)	calculate rock compressive strength, Young's Modulus and Poisson's ratio,
	(5)	Use a Mohr diagram to interpret the reservoir's shear stress rate

In order to successfully complete this assignment, you will need to complete the following Background Learning subtopics, or be familiar with the subject matter that they contain:

Structural Geology

• Stress & Strain

Coring and Core Analysis

• Complementary Core Information

Generate a stability and rock deformation model.

Upon completing this Learning Module assignment, the participant should be able to

• identify the presence and orientation of fracture systems in the reservoir

To understand formation stress response, we start by measuring the mechanical properties of representative core samples in the laboratory. This gives us information about the rock's strength and stability under a given set of conditions.

We then apply this empirical knowledge to the formation by combining our core observations with such geologic information as well logs, structure maps and regional outcrop studies.

In this assignment, you will review core descriptions for evidence of natural fractures and other tectonic activity. You will then incorporate your observations with other data sources to determine the principal stress directions in the formation.

Core analysis, including rock mechanical properties tests, have been done on selected samples from Well 2A5-NE. Early seismic measurements and log data from offset wells indicate that the reservoir is bounded by normal faults on the east and west.

Your objective in reviewing this core information is to

	(1)	determine the formation’s principal stress directions,
	(2)	and find indications of tectonic activity.

In order to successfully complete this assignment, you will need to complete the following Background Learning subtopics, or be familiar with the subject matter that they contain:

Structural Geology

• Stress & Strain

Coring and Core Analysis

• Fracture Studies

Identify and interpret production mechanisms to predict the behavior of oil, gas and gas condensate reservoirs.

Upon completing this Learning Module assignment, the participant should be able to

• identify primary reservoir drive mechanisms (solution gas drive, water drive, gas cap drive) by observing production and pressure trends.
• estimate original hydrocarbons in place, using both volumetric and material balance methods, and develop a range of estimates for technical recovery factors and reserves.

The ultimate goal of reservoir management is to optimize economically the development and production of hydrocarbons. This requires answers to three questions:

	(1)	How much hydrocarbon is there?
	(2)	How much of it is recoverable?
	(3)	How fast can it be recovered?

In other words, we need to determine , respectively, the oil and gas in place, the reserves, and the production rate.

Your job in this assignment scenario is to review the reservoir data that have been collected to this point and

• estimate the original hydrocarbon in place using volumetric and material balance methods,
• qualitatively evaluate the reservoir drive mechanisms, and
• estimate the reservoir’s primary recovery factor

In order to successfully complete this assignment, you will need to complete the following Background Learning subtopics, or be familiar with the subject matter that they contain:

Fundamentals of Reservoir Engineering

• Basic Concepts in Reservoir Engineering
• Reservoir Fluid Flow & Natural Drive Mechanisms

Reservoir Modeling and Reserves Evaluation

• Reserves Estimation

Contribute to the efforts of a multidisciplinary reservoir management team, based on a general knowledge of related disciplines.

Upon completing this Learning Module assignment, the participant should be able to

• demonstrate a basic knowledge of disciplines outside of reservoir engineering (i.e., Geology, Sedimentology, Petrophysiscs, Geophysics, etc.), and establish a working relationship with specialists from these disciplines.
• understand the role of different disciplines in the overall process of reservoir characterization and exploitation.

Much of our reservoir data comes from disciplines outside of reservoir engineering. The initial structure map, for example, may be generated from seismic measurements and geological interpretation, with subsequent information coming from well logs, cores, production data and other sources.

In this assignment, you will review the well and field data that have been gathered to date for the Upper/Middle sands, so that you can have an idea of what tools are available for describing the subsurface environment. You will also look at how various E&P disciplines may fit into the overall reservoir management task.

In order to successfully complete this assignment, you will need to complete the following Background Learning subtopics, or be familiar with the subject matter that they contain:

Reservoir Environments and Characterization

• Reservoir Characterization

Fundamentals of Reservoir Engineering

• Basic Concepts in Reservoir Engineering

Issues in Reservoir Management

• Reservoir Management of Mature Fields

Identify, monitor and evaluate drilling, workover, stimulation and well servicing proposals and activities in the context of optimizing the overall reservoir exploitation scheme.

Upon completion of this module, the participant should be able to

• contribute to the well planning process by understanding the reservoir engineering aspects of the proposed work and having a knowledge of drilling, workover and well servicing fundamentals
• work with the geologist and the drilling engineer to select well locations, target depths and casing points

Long-term exploitation strategies for this reservoir are currently being considered for the Upper/ Middle Sand reservoir. Management has appropriated funds for continued drilling, and has already approved a new well proposal for Block 5A1-SW. In this assignment, you will recommend the target depth and radius for well 5A1-SW. You will determine what mud weights to use during drilling, specify casing points, and decide on formation evaluation requirements. This reservoir has been on production for just over two years. A total of six wells have been drilled, one of which was abandoned. Production is currently averaging about 2000 barrels of oil per day under solution gas drive at well over its bubble point pressure. These wells, although initially designated as "Upper Sand" producers, expose both the Upper and Middle sand reservoirs.

In order to successfully complete this assignment, you will need to complete the following Background Learning subtopics, or be familiar with the subject matter that they contain:

Well Planning

• Well Selection
• AFE Preparation
• Well Design Considerations

Drilling Problems and Drilling Optimization

• Drilling Objectives
• Drilling Rig Hydraulics
• Abnormal Pressure Environments
• Kick Detection & Control
• Lost Circulation

Select the appropriate tubing and accessories for completing wells in keeping with the production method required for the reservoir, and to facilitate future workover, servicing and stimulation work.

Upon completion of this module, the participant should be able to

• select the proper sizes and grades of tubulars to maintain the integrity of the wellbore and handle anticipated production
• select the downhole casing and tubing accessories needed to optimize production and future well work

Well 5A1-SW is currently in the planning stage. The well specifications established so far include target depth and radius, well profile, mud weight requirements, approximate casing points and formation evaluation needs.

In this assignment, you will work on the well's completion design. You will select the completion type and tubing configuration, specify the casing and tubing diameters to be used, and design the surface and production casing strings.

The success of your design will depend on how well it handles the anticipated production, compatibility of the various hole, casing and tubing sizes, adequacy of the casing design loads, and cost.

In order to successfully complete this assignment, you will need to complete the following Background Learning subtopics, or be familiar with the subject matter that they contain:

Well Planning

• Well Design Considerations

Basic Completion Design and Practices

• General Design Criteria
• Basic Downhole Configurations
• Lift Methods
• Subsea Completions
• Completion Productivity
• Completion Planning

Select the appropriate drilling/workover fluid for meeting well objectives and, minimizing formation damage with no impact on the environment.

Upon completion of this module, the participant should be able to

• evaluate the features, benefits and limitations of various mud systems and additives, and select the one most appropriate for a given well
• specify controls on fluid properties in order to optimize drilling and workover operations

Drilling and completion fluids are essential to safe and successful well operations. In this assignment, you will select the appropriate fluids for drilling and completing Well 5A1-SW, monitor their properties, and recommend changes as needed. By the time you complete this module, you should be able to evaluate the features, benefits and limitations of various mud systems and additives, and specify controls on fluid properties for optimizing drilling and workover operations.

The AFE for drilling Well 5A1-SW has been approved, and operations are getting underway. Once drilling begins, your job will be to closely monitor the properties of the mud system you have selected, and to make changes in the mud system as operating conditions may require.

In order to successfully complete this assignment, you will need to complete the following Background Learning subtopics, or be familiar with the subject matter that they contain:

Drilling Fluids and the Circulating System

• Drilling Fluid Functions, Composition & Properties
• Drilling Rig Circulating System
• Drilling Fluid Components & Additives
• Drilling Fluid Systems
• Field Tests of Drilling Fluids

Drilling Problems and Drilling Optimization

• Drilling Rig Hydraulics

Maximize penetration rates, minimize formation damage and ensure hole stability through the proper application of drilling hydraulics principles.

Upon completion of this module, the participant should be able to

• determine the pressure losses that occur in the rig circulating system
• use basic calculation methods to determine optimal bit nozzle size, annular velocity and other rig hydraulics parameters
• diagnose drilling problems resulting from poor hydraulics practices

The objective of a drilling hydraulics program is to maximize bit life and penetration rate by efficiently removing drilled cuttings and by cleaning, cooling and lubricating the bit and drill string. The key to a sucessful hydraulic program is to deliver an optimal amount of energy to the bit.

The easiest way to control and optimize drilling hydraulics is to select the appropriate bit nozzle diameters for delivering the maximum amount of hydraulic energy to the bottom of the hole.

In assignment, you will learn to use drilling hydraulics principles to maximize penetration rates, ensure hole stability, optimize hole cleaning characteristics and minimize formation damage.

By the time you complete this module, you should be able to determine pressure losses in the rig circulating system and select the appropriate bit nozzle diameters for optimizing hydraulic energy.

In order to successfully complete this assignment, you will need to complete the following Background Learning subtopics, or be familiar with the subject matter that they contain:

Drilling Problems and Drilling Optimization

• Drilling Rig Hydraulics
• Drilling Optimization

Drill Bits

• Bit Hydraulics

Determine the most appropriate procedures, equipment, tools and cementing materials for assuring a high-quality cement job.

Upon completion of this module, the participant should be able to

• determine the volume, displacement and density requirements for cementing a casing string
• select the cement additives appropriate to a given job
• specify the casing accessories to be use on a primary cement job
• outline the steps involved in cementing a string of casing
• evaluate the results of a primary or squeeze cementing operation
• calculate the volumes and displacements required to set a cement plug

In this assignment, you will determine the appropriate procedures, materials and equipment for assuring a high-quality cement job on Well 5A1-SW. By the time you complete this module, you should be able to determine cement volume, density and displacement requirements, select cement additives, specify casing accessories, outline cementing procedures, evaluate job results, and make basic cement plug calculations.

Well 5A1-SW has been drilled to T.D., and the openhole formation evaluation program has been completed. It is now time to run and cement the production string. The purpose of this primary cement job, in which cement slurry is pumped down through the casing and up the casing-hole annulus, is to form a seal between the casing and formation, and to support the weight of the casing string.

In this module, you will determine how much cement you need for the production casing, what materials and additives you should use, what casing accessories and equipment you need, and what procedures you should follow. You will then evaluate the success of the primary cement job and, if necessary, recommend remedial work.

In order to successfully complete this assignment, you will need to complete the following Background Learning subtopics, or be familiar with the subject matter that they contain:

Cementing

• Manufacture & Classification of Oilwell Cements
• Cement Testing Procedures
• Cement Additives
• Primary Cementing Equipment
• Primary Cementing Operations
• Squeeze Cementing
• Cement Plugs
• Evaluating/Testing the Cement Job
• Fluid Flow Properties & Mud Displacement

Contribute to the planning and design of non-conventional well completions.

Upon completion of this module, the participant should be able to

• identify reservoirs that are suitable candidates for horizontal or multilateral wells
• apply knowledge of the reservoir to a selection of the well trajectory
• select the best general completion design for a horizontal or multilateral well in a given reservoir

Without directional drilling much of the world's oil and gas would be unrecoverable. Horizontal and multilateral wells, which are special applications of directional drilling technology, are a proven means of improving productivity and reducing overall development costs in certain types of reservoirs.

In this assignment, you will define basic directional drilling parameters and establish the trajectory for a possible re-drill of an existing well. You will look at the feasibility of horizontal and multilateral wells from a reservoir management perspective, and consider some of the issues involved in planning and designing these wells. By the time you complete this module, you should be able to calculate a simple well trajectory, identify candidate reservoirs for horizontal wells and select the best general completion design for a given reservoir.

Well 5C1-SW was the second well drilled in the Upper/Middle sands. Detailed log analysis and an open hole formation test indicated that the top of the Upper Sand at 14800 ft [4511 m] was below the oil-water contact. The well was subsequently plugged back with cement to the surface casing and suspended

Several members of the reservoir management team have suggested re-drilling this well upstructure to Block 5B1-NE. The drilling department will evaluate the feasibility and costs of re-drilling from below the surface casing. Your job will be to establish some of the basic directional parameters and calculating a trajectory for this well, which will be designated 5C1-SW R/D.

In order to successfully complete this assignment, you will need to complete the following Background Learning subtopics, or be familiar with the subject matter that they contain:

Directional and Horizontal Drilling

• Deviation in Vertical Wells
• Directional Drilling Tools and Techniques
• Horizontal Wells
• Drilling Hydraulics in Deviated Wells
• Drill String & Bit Considerations in Deviated Wells

Horizontal Wells: Completion and Evaluation

• Horizontal Wells in a Reservoir Management Strategy
• Horizontal Well Completions
• Matrix Stimulation of Horizontal Wells
• Hydraulic Fracturing of Horizontal Wells
• Multilateral, Multibranched and Multilevel Wells

Apply basic production engineering principles to optimizing the reservoir exploitation scheme.

Upon completion of this module, the participant should be able to

• select the optimal completion design and the proper surface and subsurface equipment for producing a flowing oil well efficiently and economically
• optimize flowing well performance based on knowledge of inflow performance, vertical lift performance and surface choke performance
• determine when artificial lift will be necessary in order to maintain oil production at desired levels, and select the most appropriate lift method for a given well
• specify design and equipment requirements for placing a well on artificial lift

In this Learning Module, you will specify the completion design for Well 5A1-SW and evaluate its performance potential. By the time you complete this module, you should be able to optimize flowing well performance using nodal analysis principles, determine when artificial lift will be necessary in order to maintain oil production, and select the best lift method for a given set of operating conditions.

Well 5A1-SW has been recently drilled to the Upper/Middle sands. It is to be completed by selectively perforating the 7-inch casing, which has been cemented at a depth of 14400 ft. In this module assignment, you will review actual and estimated field data, select the general well configuration, and specify requirements for subsurface producing equipment. You will define the well's inflow performance relationship (IPR), determine its vertical lift performance for various producing rates, and establish surface flow parameters. You will then combine these analyses to define and predict the flowing well's performance. You will also review various artificial lift methods to determine how this well will be produced once it can no longer flow.

In order to successfully complete this assignment, you will need to complete the following Background Learning subtopics, or be familiar with the subject matter that they contain:

Basic Completion Design and Practices

• General Design Criteria
• Basic Downhole Configurations
• Lift Methods
• Completion Productivity
• Completion Planning

Fluid Flow and the Production System

• Production Systems
• Inflow Performance Relationship
• Vertical Lift Performance
• Flowing Well Performance

Artificial Lift Methods (Superseded December 2006)

• Gas Lift: System Design
• Rod Pumping System Design
• Rod Pump System Monitoring
• Hydraulic Pumping System Design
• Hydraulic Pumping: Well Operation
• ESP System Design
• ESP System Monitoring & Operation
• Other Subsurface Pump Systems

Completion Equipment

• Packers
• Artificial Lift Equipment
• Downhole Completion Accessories
• Downhole Completion Accessories
• Subsurface Safety Valves (SSSVs)
• Wellhead Equipment

Optimize the perfomance of individual producing wells.

Upon completion of this module, the participant should be able to

• analyze well behavior, using nodal analysis and interpreting historical production trends
• diagnose equipment problems and/or detect production deviations
• identify production problems relating to pressure decline, water, gas or sand production, low productivity, formation damage or equipment failure
• recommend actions required for optimizing production, identify candidate wells for well servicing, stimulation and/or sand control and indicate the best method to use

In this Learning Module, you will review the actual performance of Well 5A1-SW, as well as that of several other wells in offsetting fields, in an effort to optimize their production rates. By the time you complete this module, you should be able to analyze well behavior using nodal analysis and historical production trends, diagnose equipment problems and/or detect production deviations, and recommend the appropriate action for optimizing production.

Well 5A1-SW has been completed in the Upper/Middle sands, and a production and buildup tests have been completed. You now need to see if the well's actual performance matches what was predicted before its completion. You will be looking for ways to optimize this well's production under both current and future reservoir conditions. You will also look at other wells, including two that are currently producing using electric submersible pumps and one that is planned as a rod pump completion, and make recommendations regarding their performance.

In order to successfully complete this assignment, you will need to complete the following Background Learning subtopics, or be familiar with the subject matter that they contain:

Wireline Production Operations

• Wireline Surface Equipment
• Wireline Tool String, Basic Components
• Wireline Tubing Conditioning Skills
• Wireline Remedial Operations
• Wireline Well Maintenance & Data Gathering
• Wireline Operating Requirements

Basic Completion Design and Practices

• General Design Criteria
• Basic Downhole Configurations
• Lift Methods
• Completion Productivity
• Completion Planning

Fluid Flow and the Production System

• Production Systems
• Inflow Performance Relationship
• Vertical Lift Performance
• Flowing Well Performance

Artificial Lift Methods (Superseded December 2006)

• Gas Lift: System Design
• Rod Pumping System Design
• ESP System Design
• ESP System Monitoring & Operation

Completion Equipment

• Packers
• Artificial Lift Equipment
• Downhole Completion Accessories
• Downhole Completion Accessories
• Subsurface Safety Valves (SSSVs)
• Wellhead Equipment

Determine surface facility requirements for handling the gas and liquid production volumes established for the reservoir.

Upon completion of this module, the participant should be able to

• determine fluid handling and transport requirements for surface facilities and equipment
• identify the surface facility components needed to handle the field's production, specifying their capacities and pressure ratings
• generate a general surface facilities layout showing the path of the produced fluids from the wellhead to the transportation point (pipeline or loading rack)

In this Learning Module, you will make preliminary recommendations regarding the surface production facility design for the Sucre field. By the time you complete this module, you should be able to determine basic requirements for handling produced oil, water and gas, and develop a general surface facility layout showing the path of the produced fluids from the wellhead to the sales point.

A production forecast has been generated for the Upper/Middle sands based on extended production tests and currently available rock and fluid data. You will decide how to use this forecast in sizing the surface facilities, and you will determine what types of fluid handling, separation and treating equipment will be needed. You will also specify the path that the produced fluids will follow through the production facility. Although your work will be of a very preliminary and general nature, it will be instrumental in future cost analyses, budget planning, and, ultimately, selection of an optimal reservoir development scenario.

In order to successfully complete this assignment, you will need to complete the following Background Learning subtopics, or be familiar with the subject matter that they contain:

Wellheads, Flow Control Equipment and Flowlines

• Flowlines
• Valves, Fittings & Flanges
• Production Manifolds

Fluid Separation and Treatment

• Separation of Produced Fluids
• Treatment of Separation Oil

Natural Gas Fluid Properties

• Natural Gas Fluid Systems
• Natural Gas Fluid Properties
• Temperature Measurement
• Pressure Measurement
• Volume & Flow Rate Measurement
• Gravity/ Density Measurement & Gas Composition

Design and execute a well test.

Upon completion of this module, the participant should be able to

• select candidate wells for testing and specify test objectives
• design a pressure transient test and select equipment in keeping with the stated objectives
• monitor the test and interpret the results

In this Learning Module, you will establish basic objectives and procedures for testing new wells in the Upper/Middle sands of the Sucre field. You will also review tests that were run in other reservoirs, and use the results of a drill stem test (DST) to determine well deliverability parameters. By the time you complete this module, you should be able plan, execute, monitor and interpret a simple pressure transient test.

Formation evaluation of the Upper/Middle sands--including successful production tests of Wells 4E1-NE and 5A1-SW--has established this reservoir's commercial hydrocarbon potential. The reservoir management team has generated estimates of oil in place and recovery factors; it has even predicted a production schedule and outlined basic surface facility specifications. These estimates are, however, very preliminary, and based on assumptions which may or may not prove valid over time. There is still a good deal of appraisal and planning to be done before the reservoir moves into the development stage of its life.

Your assignment in this Learning Module is to assist in the reservoir appraisal by developing general guidelines for a well testing program, based on your understanding of formation evaluation objectives and test procedures. You will also be looking at DST results from wells in other fields so that you may become familiar with basic methods of test monitoring and interpretation. In later assignments, you will become more involved in the analysis of pressure transient tests, particularly with respect to modern interpretation methods.

In order to successfully complete this assignment, you will need to complete the following Background Learning subtopics, or be familiar with the subject matter that they contain:

Fundamentals of Well Testing

• Pressure Profiles at the Wellbore
• Quantitative Well Test Interpretation
• Well Test Planning & Execution

Gas Well Testing

• Conventional & Isochronal Gas Well Tests
• Additional Testing Options
• Special Considerations in Testing Gas Wells
• Test Procedures & Regulations (Examples)

Oil Well Testing

• Basics of Pressure Transient Analysis
• Log-log Analysis
• Test Design
• Test Analysis

Drillstem Testing

• Types of Drillstem Tests
• Tool String: Conventional DST (Open Hole)
• Surface DST Equipment
• DST Design & Field Procedures
• DST Interpretation: General Aspects

Gather, view, classify and validate the multidisciplinary information required for conducting integrated reservoir studies.

Upon completing this Learning Module assignment, the participant should be able to

• access PDVSA engineering and geoscience databases and identify information that is relevant to the field under study.
• classify information according to discipline and what reservoir parameters it helps to define.

In this Learning Module, you will establish general data acquisition requirements for an integrated reservoir study of the Sucre field. You will consider both existing and potential data sources, and determine what information you need to start building a reservoir model. By the time you complete this module, you should be able to determine information needs, identify and access interdisciplinary data resources, and compile reservoir information based on the parameters to be defined.

In this Learning Module assignment, the reservoir is in the early appraisal stage of its life. Its status at the time of this assignment is as follows:

• A structure contour map has been generated from seismic data and interpretations of regional geological data.
• Well 4E1-NE, the discovery well, is currently on an extended production test.
• Well 5C1-SW tested all water, and was subsequently suspended.
• Drilling is in progress on Well 2A5-NE. A conventional coring program has been authorized, and should be getting underway soon.

The reservoir management team is already at work compiling a database of reservoir information. Your job in this assignment is to provide some ideas of what this database can contribute to the task of reservoir management, and what information should be added to it.

In order to successfully complete this assignment, you will need to complete the following Background Learning subtopics, or be familiar with the subject matter that they contain:

Hydrocarbon Indicators

• Seismic Methods & Hydrocarbon Detection

Oil Well Testing

• Basics of Pressure Transient Analysis

Reservoir Environments and Characterization

• Reservoir Characterization

Fundamentals of Reservoir Engineering

• Basic Concepts in Reservoir Engineering
• Reservoir Fluid Flow & Natural Drive Mechanisms

Reservoir Modeling and Reserves Evaluation

• Reservoir Simulation

Issues in Reservoir Management

• Reservoir Management of Mature Fields

Select and apply the appropriate well logging tools for a particular set of well conditions and reservoir study parameters.

Upon completing this Learning Module assignment, the participant should be able to

• select the appropriate logging tool(s) for evaluating a given reservoir prameter, taking into account operating conditions and limitations.
• specify procedures, surface equipment, and auxiliary tools to be employed on a logging job.

In this Learning Module, you will select and apply the appropriate tools for conducting open hole logging surveys at Well 2A5-NE, based on well conditions and formation evaluation objectives. By the time you complete this module, you should understand the basic operating principles of commonly used logging tools and be able to determine their areas of application.

Conductor casing has been set at Well 2A5-NE, and the surface hole is currently being drilled. Your tasks in this assignment are to review the surface logging program, and then to select the appropriate tools for logging from Target Depth to the shoe of the surface casing.

In order to successfully complete this assignment, you will need to complete the following Background Learning subtopics, or be familiar with the subject matter that they contain:

Validate the quality of information supplied by the logging service company to ensure that the data can be used in generating a petrophysical reservoir model.

Upon completing this Learning Module assignment, the participant should be able to

• monitor the quality control of logging procedures, including calibration, correction and choice of scales)

In this Learning Module, you will be in charge of well log quality control at Well 2A5-NE. By the time you complete this module, you should be able to define basic survey parameters, establish log scales, monitor tool responses, and confirm the validity of the data acquired from commonly used logging devices.

You are approaching target depth on Well 2A5-NE, and you will shortly be calling out the service company crew to log the 8 1/2 inch hole interval. Your job in this assignment is to establish some general guidelines for conducting logging operations, review tool calibrations and monitor survey progress.

In order to successfully complete this assignment, you will need to complete the following Background Learning subtopics, or be familiar with the subject matter that they contain:

Determine reservoir rock properties using well log analysis.

Upon completing this Learning Module assignment, the participant should be able to

• Use log analysis to identify reservoir rock properties (fluid saturation, porosity, fluid contacts, permeabilities, bulk shale content, net oil sand, fractures)

In this Learning Module, you will use basic well log interpretation techniques to identify potential pay zones, define basic reservoir properties and estimate the hydrocarbons in place in terms of reservoir volume per unit area. By the time you complete this module, you should be able to apply log analysis methods to the task of generating a petrophysical reservoir model.

The open hole formation evaluation program at Well 2A5-NE is in progress, and field copies of the lithology, resistivity and porosity logs are now available. Your job in this assignment is to review these logs and make an initial evaluation of the well's hydrocarbon potential. Your evaluation is an important first step in deciding whether to complete the well, so be sure to carefully examine the log data.

In order to successfully complete this assignment, you will need to complete the following Background Learning subtopics, or be familiar with the subject matter that they contain:

Well Log Interpretation

• Quick-Look Analysis
• Fluid Saturation
• Fractures
• Porosity
• Lithology
• Interpretation Models
• Computer Applications
• Field Studies

Dipmeter Surveys

• General Principles

Develop geological, petrophysical and sedimentological maps for use in generating a reservoir model.

Upon completing this Learning Module assignment, the participant should be able to

• generate geologic cross sections from well logs.
• draw subsurface contours and construct geologic and geophysical maps.

The original structure contour map for the Upper/Middle Sand reservoir was derived from seismic data acquired from an independent operator. Since then, three wells have been drilled, and the seismic data have undergone reprocessing and extensive additional interpretation. As a result, you now have a new base map, which shows the locations of the new wells and depth markers to the top of the Upper Sand. In this assignment, you will revise the Upper Sand structure map to reflect these new data (be careful--the updated map may or may not be similar to the original map!)

To complete the assignment, you will consider several additional formation parameters that may be conducive to subsurface contour mapping, and consider how they could be used to describe this reservoir.

In order to successfully complete this assignment, you will need to complete the following Background Learning subtopics, or be familiar with the subject matter that they contain:

Geologic Cross-Sections

• Cross-Section Elements
• Cross-Sections in Two Dimensions
• Cross-Section Diagrams in Three-Dimensions
• Cross-Sections: Computer Methods

Subsurface Mapping

• Lateral Correlation of Logged Data
• Structural Contour Maps
• Isopach & Other Subsurface Maps

Structural Geology

• Stress & Strain
• Folds
• Faults
• Unconformities
• Structural Styles

Seismic Contouring

• Contouring Fundamentals
• Contouring by Hand
• Contouring by Machine
• Interval Maps
• Contour Maps: Operations

Reservoir Environments and Characterization

• Reservoir Characterization

Issues in Reservoir Management

• Reservoir Management of Mature Fields

Elaborate and update from the maps generated during the modeling of the reservoir, the maps required by the Ministry of Energy and Mines in offical format, for the administration and control of the reserves.

Upon completing this Learning Module assignment, the participant should be able to

• access the applications used to generate MEM maps in official formatt
• generate a map using the applciations.

The Ministry of Natural Resources is a department of the National Executive of the Republic of Sucre. Its responsibilities include establishing norms and regulations for business operations in the hydrocarbon sector, in accordance with laws established by the National Legislature.

The Ministry's organization and objectives are basically the same as those of the Ministry of Energy and Mines (MEM) in the neighboring Republic of Venezuela, and the norms that it has established for oil and gas operations are identical to MEM standards. For this reason, the questions that you are asked in this assignment use MEM standards as primary reference sources.

To access the MEM references, click on the "Practical Knowledge" link

In this Assignment, you will review the present status of the Upper/Middle sand reservoir, determine what reports you need to submit to the Ministry, and decide how to classify well locations and estimated hydrocarbon reserves in keeping with established norms. You will also ensure that the symbols and conventions used in the official maps that are submitted with these reports are consistent with Ministry standards. By the time you complete the Assignment, you should be able to comply with MEM standards for reporting reserves and generating subsurface maps using accepted symbols, conventions and nomenclature.

The current status of the Upper/Middle sand reservoir is as follows:

• Well 4E1-NE, the discovery well, is on an extended production test. Permanent completion is pending.
• Well 5C1-SW was suspended after well logs and a formation test indicated that it exposed the Upper Sand below the water-oil contact.
• Well 2A5-NE has been drilled and tested, and a successful open hole formation test has been carried out.

In order to successfully complete this assignment, you will need to complete the following Background Learning subtopics, or be familiar with the subject matter that they contain:

Subsurface Mapping

• Lateral Correlation of Logged Data
• Structural Contour Maps
• Isopach & Other Subsurface Maps

Fundamentals of Reservoir Engineering

• Basic Concepts in Reservoir Engineering
• Reservoir Fluid Flow & Natural Drive Mechanisms

Reservoir Modeling and Reserves Evaluation

• Reserves Estimation

Analyze, calculate and validate compaction, subsidence and settling parameters to predict their influence on the behavior of the project and their impact on recovery, using the results of this analysis to optimize exploitation projects.

Upon completing this Learning Module assignment, the participant should be able to

• measure compaction, subsidence parameters.
• determine the significanc of these parrmeters with re determining drive mechanisms, etc.

A sedimentary formation is the product of rock particle deposition, an ongoing process in which an underlying layer of particles is buried and forced downward by succeeding layers. As deposition and burial proceed, the underlying layer is subjected to a progressively increasing overburden pressure. This increased overburden results in compaction--a reduction in the thickness and bulk volume of the underlying layer.

Compaction also takes place when fluids are withdrawn from a subsurface formation. Fluid withdrawal causes a decrease in pore pressure, which in turn increases the grain-to-grain, or matrix pressure of the rock particles and causes them to compact. The amount of compaction that occurs in a given formation depends only upon the difference between the vertically applied overburden pressure and the fluid, or pore pressure. Thus, the uniaxial compaction of a rock sample of thickness h can be expressed as

     DV_b/ V_b = Dh/h

Depending on geological conditions, subsurface compaction may be associated with varying degrees of subsidence, or sinking of the ground at the surface.

Compaction and its associated effect of surface subsidence can, in certain situations, have significant effects on reservoir management strategies and field operations. In this Assignment, you will build your general understanding of these phenomena and see how they can influence reservoir engineering decisions. You will also look at a system that has been developed by PDVSA to describe and predict compaction and subsidence in areas where they are of particular concern.

By the time you complete this assignment, you should be able to identify situations where compaction and subsidence may be important considerations in a reservoir management strategy, and you should be able to begin using computer-based tools for predicting compaction and subsidence under various conditions.

PLEASE NOTE:The Assignment for this Learning Module refers to the HUNDCALC subsidence prediction system developed by PDVSA (Maraven), and described in the document Procesos Operativos y de Calculos Del Sistema de Prediccion de Hundimiento "HUNDCALC" (REN-836, author Carlos Wulff, November 1994). If you cannot access this document through your company's Intranet, or by clicking on the "Practical Knowledge" link, please contact your mentor or system administrator.

In order to successfully complete this assignment, you will need to complete the following Background Learning subtopics, or be familiar with the subject matter that they contain:

Reservoirs

• Rock Properties
• Diagenesis

Porosity Evolution in Sandstone Reservoirs

• Diagenesis

Drilling Problems and Drilling Optimization

• Abnormal Pressure Environments

Reservoir Environments and Characterization

• Sandstone Reservoir Environments

Fundamentals of Reservoir Engineering

• Basic Concepts in Reservoir Engineering
• Reservoir Fluid Flow & Natural Drive Mechanisms

Analyze and interpret pressure and production data for incorporation into the reservoir model.

Upon completion of this module, the participant should be able to

• review and acquire well test information
• validate pressure test information
• prepare well test data for analysis
• diagnose and interpret the pressure test
• design and interpret production records; analyze production behavior

Well 4E1-NE is the first well drilled in the Upper/Middle Sand reservoir. The well was completed with 7-inch casing, selectively perforated and placed on an extended production test. Testing was conducted in several stages. The first stage, which is the subject of this assignment, involved testing 16 feet of interval in the upper portion of the identified pay intervals. This test was designed to gather information on reservoir flow characteristics, and in particular, to determine the nature of a nearby fault that had been identified on the structure map. Your job in this assignment is to review the data from this initial test and evaluate the reservoir permeability, near-wellbore effects and boundary effects.

In order to successfully complete this assignment, you will need to complete the following Background Learning subtopics, or be familiar with the subject matter that they contain:

Well Log Interpretation

• Fluid Saturation
• Porosity
• Lithology

Fundamentals of Well Testing

• Pressure Profiles at the Wellbore
• Defining the Reservoir Model
• Quantitative Well Test Interpretation
• Well Test Planning & Execution

Oil Well Testing

• Basics of Pressure Transient Analysis
• Log-log Analysis
• Test Design
• Test Analysis

Establish flow units within the reservoir.

Upon completing this Learning Module assignment, the participant should be able to

• Establish the areal and vertical distribution of zones with similar behavior in agreement with the reservoir model.
• Identify and delineate the rock volumes with sedimentological, petrophysical and reservoir properties that enable hydraulic communication.

Most reservoirs are not homogeneous. Rather, they exhibit complex variations in continuity, thickness patterns and other properties, including porosity, permeability and capillary pressure. A reservoir is typically subdivided into zones or areas based upon differences in rock properties. The complexity of reservoir rock imposes a challenge to geoscientists and engineers in applying available technologies and their experience to improving oil and gas recovery.

The purpose of geological mapping is to identify flow units that contain oil and gas, and once they are found, to apply geologic evidence and concepts toward achieving the most efficient development and production of these prospects. However, it is important to remember that these geologic maps are never finished. When new wells are drilled or old wells are re-examined, new information becomes available, and the extent and geometry of flow units must be updated. Original maps may be based upon a few scattered control points. This means that in the early stages of geological work, a careful study of the local area should be made.

Lithofacies maps are quite helpful in defining various reservoir rock types. The correlation of a number of reservoir properties, including porosity and permeability, becomes much more meaningful when applied to a specific rock type.

During the production phase of a reservoir, more information about flow units is obtained by transient well testing and careful monitoring of individual well performance. Reservoir pressure maps are particularly useful for evaluating reservoir continuity. The areal distribution of reservoir pressure in different zones as a function of time can help us to identify pay discontinuities and flow barriers. Vertical pressure profiles are also useful in defining the effect of vertical permeability within a given reservoir section.

History matching of field performance, using a numerical reservoir simulator, can provide great insight into the continuity of flow units and reservoir properties in inter-well areas where there is no measurements. In this process, the geological properties such porosity, permeability and pay continuity are changed in order to match the observed field performance.

Different steps in gathering data for flow unit determination are:

In the geological phase:

• General reservoir configuration
• Fluids distribution
• Continuity and thickness
• Rock type, porosity and permeability cutoffs
• Fluid contacts
• Vertical stratification

During the production phase:

• Logging
• Well performance
• Well testing
• Relative permeability, capillary pressure and wettability tests
• Inter-well tracers

In this assignment, you will be taking a short break from your work in the Sucre field, while the geologists on the reservoir management team prepare an analysis of some of the information that has been gathered so far from the upper/middle sands. During this time you will work on identifying the flow units within another reservoir where your company is actively involved in the Nuri formation.

In order to successfully complete this assignment, you will need to complete the following Background Learning subtopics, or be familiar with the subject matter that they contain:

Dipmeter Surveys

• General Principles

Geologic Cross-Sections

• Cross-Section Elements

Subsurface Facies Analysis

• Sedimentary Environments & Facies
• Lithology
• Sedimentary Structures, Geometry & Facies
• Sandstone Reservoir Facies
• Carbonate Reservoir Facies

Classic Sequence Stratigraphy

• Sequence Stratigraphy
• Interpretation of Stratigraphic Sequences

Applications of Petroleum Geochemistry

• Geochemical Programs in Petroleum Exploration

Cased Hole Logging

• Qualitative Flow Evaluation

Reservoir Environments and Characterization

• Reservoir Characterization

Fundamentals of Reservoir Engineering

• Basic Concepts in Reservoir Engineering

Apply analytical and numerical simulation techniques to the development, testing and refining of a reservoir model, and the generation of an optimal reservoir exploitation plan.

Upon completion of this module, the participant should be able to

• define reservoir simulation objectives
• define simulator geometry and dimensions, and assign flow equations to the proposed model
• define simulator grid and boundary conditions
• compile reservoir model input parameters
• develop finite-difference approximations to solve the flow equations
• plan numerical simulation computer runs and interpret the results
• use simulation results to determine the optimum exploitation scheme

A typical reservoir simulation study is conducted in four stages:

1. Gather all relevant reservoir data.
2. Initialize the developed model.
3. Validate the model using a history matching process.
4. Forecast the reservoir's future behavior.

Once the structure, thickness, porosity and permeability maps are obtained, the data need to be discretized according to the gridding system used. Fluid properties are entered into the model either using a data table or in the form of a correlation. For multi-phase flow problems, relative permeability relationships and capillary pressure curves also need to be obtained.

Models are typically initialized with respect to the water/oil or gas/oil contact depths and a reference datum-level pressure value.

For the initialization, the simulator is run until the hydrostatic equilibrium of the existing phases is established.

Validation of the model requires a detailed production history of all wells in the reservoir. The production data should contain information about open intervals, well stimulations and production rate of each phase (oil, gas, water).

After the model is history matched against the existing production data, it can be used to predict future reservoir behavior for different development scenarios.

Keep in mind that these predictions are only as good as the basic input that was entered into the model.

Your assignment here is to gather all the iso-surface maps and fit a body-centered grid on top of the reservoir structure.

You also need to collect all the PVT data that will be used during the simulation.

In order to successfully complete this assignment, you will need to complete the following Background Learning subtopics, or be familiar with the subject matter that they contain:

Fundamentals of Reservoir Engineering

• Basic Concepts in Reservoir Engineering
• Reservoir Fluid Flow & Natural Drive Mechanisms

Improved Recovery Processes

• Secondary Recovery: Waterflooding & Gas Injection
• Enhanced Recovery: Miscible Flooding

Reservoir Modeling and Reserves Evaluation

• Reservoir Simulation

Acquire and analyze the necessary data for optimizing reservoir surveillance.

Upon completion of this module, the participant should be able to acquire and analyze pressure data, PVT reports, production records, injection records, production tests, fluid sampling, injectivity tests, and other information for the purpose of monitoring reservoir behavior.

Reservoir surveillance is a process of identifying, gathering and interpreting the information needed to effectively manage the reservoir and maximize economic hydrocarbon recovery. This process become more and more critical as a field passes through the various phases of primary, secondary and enhanced recovery.

In this assignment, you will plan a data acquisition program for the Upper/Middle Sands that includes the following elements:

1. Present and future objectives
2. Data requirements
3. Data sources
4. Acquisition methods
5. Interpretation of collected data

By the time you complete this assignment, you should be able to acquire and analyze pressure data, PVT reports, production records, injection records, production tests, fluid sampling, injectivity tests, and other information for the purpose of monitoring reservoir behavior.

The exploration/appraisal program for this reservoir is currently in its third year. So far, four wells have been drilled: 4E1-NE, 5C1-SW (suspended), 2A5-NE and 5A1-SW.

In order to successfully complete this assignment, you will need to complete the following Background Learning subtopics, or be familiar with the subject matter that they contain:

Reservoir Environments and Characterization

• Reservoir Characterization

Fundamentals of Reservoir Engineering

• Basic Concepts in Reservoir Engineering
• Reservoir Fluid Flow & Natural Drive Mechanisms

Reservoir Modeling and Reserves Evaluation

• Reservoir Simulation
• Reserves Estimation

Issues in Reservoir Management

• Reservoir Management of Mature Fields

Integrated Reservoir Characterization

• Assembly and Review of Existing Data
• Data Acquisition
• Data Analysis and Interpretation
• Data Integration
• Recommended Processes

Integrate multidimensional seismic information and geological data to optimize the processes of reservoir monitoring and exploitation.

Upon completion of this module, the participant should be able to establish a basis for integrating geophysical and geological data and incorporating them into the reservoir surveillance program.

Reservoir surveillance is a process of gathering and analyzing the information necessary to control operations and maximize the economic recovery of hydrocarbons. Geologists and geophysicists play a key role in this process, from early exploration and appraisal to the mature stages of production.

In this assignment, you will consider how various geological and geophysical tools can be used for reservoir monitoring, and determine their applicability to the surveillance program for the Upper/Middle Sands.

By the time you complete this assignment, you should be able to establish a basis for integrating geophysical and geological data and incorporating them into the reservoir surveillance program.

The exploration/appraisal program for this reservoir is currently in its third year. So far, four wells have been drilled: 4E1-NE, 5C1-SW (suspended), 2A5-NE and 5A1-SW.

In order to successfully complete this assignment, you will need to complete the following Background Learning subtopics, or be familiar with the subject matter that they contain:

Gravity and Magnetics

• Borehole Gravity

Cased Hole Logging

• Formation Evaluation in Cased Holes

Reservoir Environments and Characterization

• Sandstone Reservoir Environments
• Reservoir Characterization

Other Geophysical Techniques

• Borehole Velocity Measurements
• Synthetic Seismogram

Crosswell Seismology

• When to Run a Crosswell Survey
• Crosswell Data Acquisition
• Crosswell Seismic Data Processing and Analysis
• Crosswell Seismology Recommended Practices

Integrated Reservoir Characterization

• Assembly and Review of Existing Data
• Data Acquisition
• Data Analysis and Interpretation
• Data Integration
• Recommended Processes

Update the geological model of the reservoir.

Upon completion of this module, the participant should be able to apply information from newly acquired well logs, core samples and other data sources to refine the geological model of the reservoir, including its structure, stratigrapy, dimensions and boundaries.

The geological model is a basic element of any reservoir description. It characterizes such parameters as reservoir structure, stratigraphy and dimensions based on logs, core analyses and other data. These parameters are essential to estimating hydrocarbon-in-place and reserves potential.

In this assignment, you will review available information from the Upper/Middle Sands and compare it with the present geological model. You will then revise the geological model as necessary. Based on your interpretations, you will develop important insights into the reservoir continuity and depositional environment, and establish or confirm the reservoir limits.

By the time you complete this module, you should be able to apply information from well logs, core samples and other data sources to refine the geological model of the reservoir, including its structure, stratigrapy, dimensions and boundaries.

The exploration/appraisal program for the Upper/Middle Sands has been completed, and the reservoir is currently entering its first development year. Wells drilled and evaluated to date are 4E1-NE, 5C1-SW (suspended), 2A5-NE, 5A1-SW and 5A2-SE.

In order to successfully complete this assignment, you will need to complete the following Background Learning subtopics, or be familiar with the subject matter that they contain:

Well Log Interpretation

• Fluid Saturation
• Lithology

Subsurface Facies Analysis

• Sedimentary Environments & Facies
• Lithology
• Sedimentary Structures, Geometry & Facies
• Sources of Information
• Sandstone Reservoir Facies

Reservoir Environments and Characterization

• Sandstone Reservoir Environments
• Carbonate Reservoir Environments
• Reservoir Characterization

Fundamentals of Reservoir Engineering

• Basic Concepts in Reservoir Engineering

Update the petrophysical model of the reservoir.

Upon completion of this module, the participant should be able to use well logs, cores, correlations and other tools to establish the distribution of petrophysical properties in the reservoir.

Reservoir quality is determined primarily by the distribution of petrophysical properties such as porosity and permeability, pore size distribution and pore geometry, and the presence of pore-filling materials that may have an effect on productivity or hydrocarbon recovery efficiency. Other important factors, such as relative permeability and capillary pressure relationships, are related to rock wettability and capillary pressure effects. Thus, in order to fully describe reservoir quality, it is necessary to have a knowledge of the composition and characteristics of the reservoir fluids, as swell as the rock pore system.

In this assignment, you will determine reservoir properties for input into the Upper/Middle Sands petrophysical model. By the time you complete this assignment, you should be able to use well logs, cores, correlations and other tools to establish the distribution of petorphysical properties in the reservoir.

The exploration/appraisal program for the Upper/Middle Sands has been completed, and the reservoir is currently entering its first development year. Wells drilled and evaluated to date are 4E1-NE, 5C1-SW (suspended), 2A5-NE, 5A1-SW and 5A2-SE.

In order to successfully complete this assignment, you will need to complete the following Background Learning subtopics, or be familiar with the subject matter that they contain:

Well Log Interpretation

• Quick-Look Analysis
• Fluid Saturation
• Porosity
• Lithology

Coring and Core Analysis

• Bottomhole Coring (Coring While Drilling)
• Major Types of Core Analysis
• Core Sample Preparation
• Porosity Measurement
• Permeability Measurement
• Saturation Measurement
• Core Analysis Reports
• Special Core Analysis

Update the reservoir model.

Upon completion of this module, the participant should be able to

• Incorporate new production data (selective & differential) into the reservoir model, along with new information from well/core analyses.
• Refine the reservoir model based on differences between predicted and actual pressure and production data.

A preliminary reservoir model of the Upper/Middle Sands was generated during the exploration/appraisal period. In this assignment, you will review the most current available data and history-match the reservoir’s actual performance with that predicted by the original model. Based on the results of the history match, you may choose to modify one or more of the following parameters:

• Data summary
• Grid data
• Thickness data
• Porosity data
• Permeability data
• Saturation data

With this updated reservoir model, you can test different exploitation scenarios to determine which one results in the optimal economic recovery.

The field is presently under development, during which time it has been placed on limited production. Active wells include 4E1-NE, 2A5-NE, 5A1-SW and 5A2-SE.

In order to successfully complete this assignment, you will need to complete the following Background Learning subtopics, or be familiar with the subject matter that they contain:

Perforating

• Perforating & Production Performance

Fundamentals of Reservoir Engineering

• Basic Concepts in Reservoir Engineering
• Reservoir Fluid Flow & Natural Drive Mechanisms

Reservoir Modeling and Reserves Evaluation

• Reservoir Simulation
• Reserves Estimation

Issues in Reservoir Management

• Reservoir Management of Mature Fields

Use economic evaluation methods to select the most profitable project and/or exploitation strategy, and formulate a project budget.

Upon completion of this module, the participant should be able to apply economic evaluation techniques that are necessary for analyzing proposed long-range exploitation strategies and/or projects in the areas of reservoir, drilling and production.

Based on reservoir model and well performance predictions that were generated during the exploration/appraisal period, the reservoir management team is currently looking at 3 potential development scenarios for the primary recovery stage:

	Case 1a	Case 2a	Case 3a
MDR (Maximum Design Rate)	7500 STB/D [1193 m3/D]	15000 STB/D [2385 m3/D]	22500 STB/D [3578 m3/D]
Exploration/appraisal wells to be completed	4	4	4
Additional wells to be drilled and completed	1	6	11
Total number of wells	5	10	15

The simulator runs used to generate these cases were based on the following assumptions:

• Volumetric (closed pressure boundary) reservoir.
• Production begins in the first production year at the MDR, even though the reservoir actually produced at low rates under test conditions during the exploration/appraisal stage.
• Average initial production per well = 1500 STB/D [apx. 240 m³/D]—under the assumed reservoir parameters, this appears to be the maximum natural flow rate that is sustainable for a significant time period.

In this assignment, you will compile the available information and generate net discounted cash flow predictions for each of these cases. You will then evaluate each case in terms of its primary economic indicators, taking into account the sensitivity of the evaluation to uncertainties in the input parameters.

NOTE: An MS Excel spreadsheet, Proj_Template, has been included as a reference for this assignment. You may use this spreadsheet to enter input parameters and run economics for each Case. If you do so, be sure to save each case as a separate file, because you will be referring back to it as you progress through the assignment.

In order to successfully complete this assignment, you will need to complete the following Background Learning subtopics, or be familiar with the subject matter that they contain:

Risk Analysis Applied to Petroleum Investments

• Risk Analysis Fundamentals
• Probability Distributions
• Monte Carlo Simulation Models
• Competitive Bidding

Prepare the required permission requests for drilling, workover/recompletion, stimulation, abandonment and well servicing operations to satisfy the established legal requirements of governmental regulatory organizations.

Upon completion of this module, the participant should be able to follow proper procedures for obtaining permission to conduct drilling, workover/recompletion, stimulations, abandonment proposals and well servicing operations, in accordance the established legal requirements of the MEM, MARNR and other official organizations.

The Ministry of Natural Resources is a department of the National Executive of the Republic of Sucre. Its responsibilities include establishing norms and regulations for business operations in the hydrocarbon sector, in accordance with laws established by the National Legislature.

As is true for similar regulatory agencies in other countries, the Ministry of Natural Resources oversees the permitting of oil and gas operations, including those that pertain to well drilling, completion workover and abandonment.

The Ministry's permitting requirements are basically the same as those of the Ministry of Energy and Mines (MEM) in the neighboring Republic of Venezuela, and the norms that it has established for oil and gas operations are identical to MEM standards. For this reason, the questions that you are asked in this assignment use MEM standards as primary reference sources.

In this learning module assignment, you will apply the permitting requirements of the Ministry in the following areas:

• Drilling of a new well
• Workover and abandonment operations
• Project management as it relates to improved recovery operations, well spacing critieria and gas utilization requirements.

In order to successfully complete this assignment, you will need to complete the following Background Learning subtopics, or be familiar with the subject matter that they contain:

Apply the laws, regulations and norms relating to personal, environmental and industrial safety as they apply to oil and gas operations.

Upon completion of this module, the participant should be able to

• apply the laws, regulations and norms in matters of personal, industrial and environmental safety, with the objective of protecting the integrity of persons, installations, equipment and the environment.
• identify instances in which safe practices are not being followed, and take steps to correct the situation

The reservoir is currently in its development and early production stages. Drilling, construction and production activities are fully underway. In each of these activities, it is imperative to maintain safe operations, protect the health and well-being of personnel, and preserve the environment.

In this module assignment, you will be observing drilling rig operations with an eye toward your own personal safety and that of others at the wellsite. You will review incident descriptions from various field locations and try to determine what went wrong in each case and how the incident could have been prevented. And you will look at several issues related to fire protection at an upstream production facility.

In order to successfully complete this assignment, you will need to complete the following Background Learning subtopics, or be familiar with the subject matter that they contain:

Oilfield Safety

• Emergency Prepareness
• Incident Reporting & Investigation
• Safety Hazards in Oil & Gas Production
• Safe Work Practices
• Safety & Control of Site Activities
• Fire Prevention & Control

Optimize reservoir management and control decisions using surveillance techniques, information systems, technical indicators and financial guidelines.

Upon completion of this module, the participant should be able to do the following:

• Manage available resources (e.g., reserves, assets, personnel, budget) in order to maximize hydrocarbon reserves and minimize recovery cost.

• Make appropriate reservoir management and control decisions with the aid of surveillance techniques, information systems and technology applications to generate pressure and production histories, maps and other key reservoir data.

The Upper/Middle Sands have been on production for about 11 months. Fifteen wells are currently active, and the information that you have available includes both detailed and summary reports of pressure and production behavior. In this assignment, you will use this information to refine the reservoir description, improve well performance and work toward developing an optimal exploitation strategy.

In order to successfully complete this assignment, you will need to complete the following Background Learning subtopics, or be familiar with the subject matter that they contain:

Basic Completion Design and Practices

• Completion Productivity

Oil Well Testing

• Basics of Pressure Transient Analysis

Fluid Flow and the Production System

• Production Systems
• Inflow Performance Relationship
• Vertical Lift Performance
• Flowing Well Performance

Production Performance Evaluation

• Production Rate Decline Curves

Fundamentals of Reservoir Engineering

• Basic Concepts in Reservoir Engineering
• Reservoir Fluid Flow & Natural Drive Mechanisms

Improved Recovery Processes

• Secondary Recovery: Waterflooding & Gas Injection

Reservoir Modeling and Reserves Evaluation

• Reserves Estimation

Issues in Reservoir Management

• Reservoir Management of Mature Fields

Evaluate the improved recovery potential of the reservoir.

Upon completion of this module, the participant should be able to

• Apply basic screening criteria and determine a reservoir’s suitability for various improved recovery processes, including waterflooding and enhanced oil recovery.
• Observe waterflood performance and perform basic recovery calculations, based on a frontal advance model and analysis of fractional flow curves.
• Determine the displacement efficiency of a pilot waterflood.

Improved recovery, in the context of this assignment, refers to processes that supplement natural reservoir drive mechanisms. These processes are generally grouped into two main categories:

• secondary recovery, which includes waterflooding and immiscible gas injection
• enhanced oil recovery (EOR), which includes miscible, chemical and thermal methods.

Although individual processes vary widely in type and applicability to particular conditions, they have one objective in common: to improve the displacement efficiency of hydrocarbons from the reservoir.

In this assignment, you will review the performance of the Upper/Middle Sands under primary depletion and conduct a preliminary waterflood screening, including a pilot flood to serve as a field trial of the process. The reservoir has been on production for just over one year. There are currently 15 active wells.

In order to successfully complete this assignment, you will need to complete the following Background Learning subtopics, or be familiar with the subject matter that they contain:

Basic Completion Design and Practices

• Completion Productivity

Oil Well Testing

• Basics of Pressure Transient Analysis

Fluid Flow and the Production System

• Production Systems
• Inflow Performance Relationship
• Vertical Lift Performance
• Flowing Well Performance

Production Performance Evaluation

• Production Rate Decline Curves

Fundamentals of Reservoir Engineering

• Basic Concepts in Reservoir Engineering
• Reservoir Fluid Flow & Natural Drive Mechanisms
• Reservoir Fluid Flow & Natural Drive Mechanisms

Improved Recovery Processes

• Secondary Recovery: Waterflooding & Gas Injection
• Secondary Recovery: Waterflooding & Gas Injection
• Enhanced Recovery: Miscible Flooding

Reservoir Modeling and Reserves Evaluation

• Reservoir Simulation
• Reserves Estimation

Issues in Reservoir Management

• Reservoir Management of Mature Fields
• Reservoir Management of Mature Fields

Develop a strategic scenario and budget for implementing a reservoir development scheme and producing actual reserves.

Upon completion of this module, the participant should be able to

• Use reservoir studies to develop a resource base (drilling plans, future improved recovery, information acquisition, application of new technologies, facilities and infrastructure).

Evaluate reservoir exploitation schemes through the use of corporate management indicators

The Upper/Middle sands project is about to complete its ninth year (fourth production year). You have recently concluded a twenty-month pilot waterflood in the fault block occupied by Wells 4E2-SE and 4D2-SW. In this assignment, you will evaluate the results of this pilot project in preparation for implementing a field-wide waterflood. You will then address the practical aspects of implementing the full-scale project, generate a development scenario based on the data that you have gathered during the primary production stage, and formulate a project budget.

In order to successfully complete this assignment, you will need to complete the following Background Learning subtopics, or be familiar with the subject matter that they contain:

Fundamentals of Reservoir Engineering

• Basic Concepts in Reservoir Engineering
• Reservoir Fluid Flow & Natural Drive Mechanisms

Improved Recovery Processes

• Secondary Recovery: Waterflooding & Gas Injection
• Exercise No. 6
• Exercise No. 7

Reservoir Modeling and Reserves Evaluation

• Reserves Estimation

Issues in Reservoir Management

• Reservoir Management of Mature Fields

Understand and apply reservoir surveillance and control techniques to confirm the materialization of the proposed strategies in the reservoir exploitation scheme

Upon completion of this module, the participant should be able to

• compare actual reservoir behavior to various performance prediction tools and account for differences
• evaluate the effectiveness of the exploitation strategy

explain reasons why actual reservoir performance deviated from initial predictions

The Upper/Middle Sands have been on production for more than 20 years, 15 of them under waterflood. On the basis of daily average production, this reservoir has already passed its economic limit, with water cuts routinely exceeding 90 percent. But thanks to the efforts of field personnel in applying good production practices and bringing operating costs down to a minimum, the field is still making a small profit. It remains to be seen whether this field has additional potential through a realignment of the waterflood or implementation of enhanced oil recovery methods.

In order to successfully complete this assignment, you will need to complete the following Background Learning subtopics, or be familiar with the subject matter that they contain:

Fundamentals of Reservoir Engineering

• Basic Concepts in Reservoir Engineering
• Basic Concepts in Reservoir Engineering
• Reservoir Fluid Flow & Natural Drive Mechanisms
• Reservoir Fluid Flow & Natural Drive Mechanisms

Improved Recovery Processes

• Secondary Recovery: Waterflooding & Gas Injection
• Secondary Recovery: Waterflooding & Gas Injection
• Enhanced Recovery: Miscible Flooding
• Exercise No. 6
• Exercise No. 7

Reservoir Modeling and Reserves Evaluation

• Reservoir Simulation
• Reserves Estimation
• Reserves Estimation

Issues in Reservoir Management

• Reservoir Management of Mature Fields
• Reservoir Management of Mature Fields

Analyze scenarios, make suitable contract models and study special projects in areas of the exploitation macro process, assuring business profitability and respecting the prevailing laws and norms of contracts.

Upon completion of this module, the participant should be able to

• analyze field projects and generate contract models
• evaluate contracts in terms of project profitability

As a reservoir manager, you are certain to spend much of your time dealing with companies that provide products, materials or services ranging from downhole tools to simulation software to engineering expertise. You may also work with research institutions, government agencies, other operating companies, and even with private individuals. All of these working relationships are governed by legal agreements, or contracts.

A contract defines the rights that each party has in a business relationship, the obligations that each party has toward the other, and the legal, fiscal and operating terms under which these rights and obligations are maintained. When properly drafted and negotiated in good faith, a contract works to the mutual benefit and protection of both parties. It is important, therefore, that you understand and be able to apply key contract provisions.

In this Learning Module, you will focus on two types of contracts: a term sheet for a Turnkey Drilling Contract with Daywork Provisions, patterned after the International Association of Drilling Contractors’ model (IADC--1998), and a Master Agreement for Contract Services, patterned after models developed by the IADC and the International Association of Geophysical Contractors (IAGC).

In order to successfully complete this assignment, you will need to complete the following Background Learning subtopics, or be familiar with the subject matter that they contain:

Define basic drilling and well completion requirements based on reservoir management objectives. Identify critical logistical issues and HSE considerations. Generate budget cost estimate.

Upon completion of this module, the participant should be able to

• Review an initial well proposal and identify key drilling and completion objectives.
• Gather and evaluate offset data and other information pertinent to the well objectives.
• Document and evaluate indicators of potential drilling hazards and/or HSE risks.
• Identify appropriate methods for predicting pore pressures, fracture pressures, and subsurface temperatures, and plot predicted pressures and temperatures versus depth.
• Determine formation fluids to be encountered and potential contaminants.
• Outline critical issues relating to surface location, including those related to logistics, safety and environmental protection.
• Generate a budget-level estimate of dry-hole and total well costs.

The Asset Management Team responsible for PETROS Corporation’s portion of the Tremont onshore field has recently completed an appraisal of the 6th Zone reservoir, and is now preparing a development program. The team has given you a proposed bottomhole location for the first development well, Adams 8. The target location is in Block D-4, approximately 0.5 km [1640 ft] from the property boundary between PETROS Corporation and Apex Oil & Gas Company. The discovery well for the 6th Zone anticline was Apex's Copley 1. Four additional wells (Copley 3, Adams 4, Adams 6 and Adams 7) have either tested or are currently producing commercial quantities of oil; Three others (Copley 2, Stuart 1 and Adams 5) were drilled outside of the structure boundaries and subsequently abandoned. Your tasks in this assignment are to establish the drilling objectives for this well in keeping with the overall reservoir management strategy, and to identify some of the key issues to be addressed in the well planning process.

In order to successfully complete this assignment, you will need to complete the following Background Learning subtopics, or be familiar with the subject matter that they contain:

Well Planning

• Well Selection
• AFE Preparation
• Well Plan Organization & Data Gathering
• Well Design Considerations
• Rig Design Considerations
• Procedures

Drilling Problems and Drilling Optimization

• Drilling Objectives
• Abnormal Pressure Environments
• Hydrogen Sulfide

Define basic well design parameters, including well profile, casing points and casing/hole diameters. Design casing strings and outline cementing requirements. Select surface equipment components. Generate preliminary cost estimates for inclusion in AFE.

Upon completion of this module, the participant should be able to

• Select a surface location for a new well and establish an optimal target radius
• Pick casing points and specify casing and hole diameters for each drilled section
• Establish a well trajectory in keeping with overall drilling objectives
• Select casing weights, grades and connections based on consideration of maximum load conditions
• Determine general requirements for primary cementing operations.
• Specify wellhead equipment components and their working pressure ratings.

An initial review of the Adams 8 well proposal served to clarify the drilling objectives, identify critical well planning issues and provide some knowledge of the surface and subsurface environments. It is now time to start the designing the well. The starting point will be to finalize the surface and bottomhole locations so that you can establish a well profile. At the same time, you will pick your casing points, decide on the casing and hole diameters for each interval and recommend the working pressure ratings for the wellhead components. You will then specify the weights, grades and connections to be used for each casing string, and outline the primary cementing requirements for the surface casing. Finally, you will provide a cost estimate to be used in preparing the AFE for this well.

In order to successfully complete this assignment, you will need to complete the following Background Learning subtopics, or be familiar with the subject matter that they contain:

Wellheads, Flow Control Equipment and Flowlines

• Casing & Tubing Head Equipment

Well Planning

• Well Selection
• AFE Preparation
• Well Plan Organization & Data Gathering
• Well Design Considerations
• Rig Design Considerations
• Procedures

Directional and Horizontal Drilling

• Directional Drilling Tools and Techniques

Drilling Problems and Drilling Optimization

• Drilling Objectives
• Hydrogen Sulfide

Completion Equipment

• Tubulars

Design mud program for each hole section. Establish well control precautions and procedures. Design drill string and bottomhole assembly. Plan bit and hydraulics programs. Evaluate rig specifications and capabilities.

Upon completion of this module, the participant should be able to:

• Outline mud system specifications for individual hole sections based on well conditions and drilling objectives.
• Establish basic well control requirements.
• Specify circulating system requirements and evaluate hydraulics practices based on offset well performance.
• Review offset bit performance as a basis for developing bit selection criteria for a new well.
• Provide general recommendations for the drill string configuration and design of the bottomhole assembly.
• Review rig specifications and capabilities in the context of drilling program requirements.

In this assignment, you will address various aspects of planning and carrying out the drilling program for Adams 8, a new development well in the Tremont field. Your work will include designing the mud and hydraulics programs, reviewing basic well control precautions, establishing guidelines for bit selection, and designing the drill string. Although you will not be directly involved in reviewing bids and selecting the drilling contractor, you will be providing input regarding power requirements, hoisting capabilities and circulating system capacities that will be valuable in the rig selection process. Your goal in this assignment is to develop a program that ensures safe well operations, minimizes drilling cost and meets the design requirements of the well.

In order to successfully complete this assignment, you will need to complete the following Background Learning subtopics, or be familiar with the subject matter that they contain:

Well Planning

• Rig Design Considerations

Drill String Components

• Kelly
• Drill Pipe
• Drill Collars
• Heavy Wall Drill Pipe
• Bottomhole Assembly Tools

Drilling Fluids and the Circulating System

• Drilling Fluid Functions, Composition & Properties
• Drilling Rig Circulating System
• Drilling Fluid Components & Additives
• Drilling Fluid Systems
• Field Tests of Drilling Fluids
• Clay Chemistry
• Solids Control

Directional and Horizontal Drilling

• Deviation in Vertical Wells

Drilling Problems and Drilling Optimization

• Drilling Objectives
• Drilling Rig Hydraulics
• Abnormal Pressure Environments
• Kick Detection & Control
• Lost Circulation
• Borehole Instability
• Hydrogen Sulfide
• Drilling Optimization

Drill Bits

• Bit Design (Rolling Cutter Types)
• Bit Design (Fixed Cutter Types)
• Bit Hydraulics
• Bit Selection Criteria
• Bit Grading & Evaluation
• Bit Operating Guidelines

Monitor drilling parameters and well progress. Take steps to optimize bit runs, mud system performance and directional control. Ensure HSE compliance. Anticipate drilling problems and work to minimize their impact.

Upon completion of this module, the participant should be able to:

• Optimize drilling performance through careful monitoring and analysis of well parameters.
• Select bottomhole assembly configurations for various hole intervals and operating conditions.
• Oversee routine cementing operations in shallow hole intervals.
• Diagnose a stuck pipe incident and outline fishing procedures.
• Monitor drilling parameters for indications of abnormal pore pressure and take the approriate initial actions in response to a potential kick situation.

The drilling crew is ready to spud Adams 8, and you are in charge of day-to-day operations. To begin this assignment, you will approve the bottomhole assembly configuration for the surface hole interval and supervise the running and cementing of a 13 3/8 inch [339.7 mm] casing string. Next, you will monitor the progress of the intermediate hole section and take steps to optimize drilling performance. Finally, you will begin drilling below the intermediate casing, paying particular attention to detecting a pressure transition zone that has already been identified at other 6th Zone wells. By way of caution, note that drilling operations do not always proceed smoothly. Although this assignment is fairly straightforward, be prepared to address problems that may occur.

In order to successfully complete this assignment, you will need to complete the following Background Learning subtopics, or be familiar with the subject matter that they contain:

Oilfield Safety

• Emergency Prepareness
• Incident Reporting & Investigation
• Safety Hazards in Oil & Gas Production
• Safe Work Practices

Well Planning

• Well Design Considerations
• Rig Design Considerations
• Procedures

Drill String Components

• Kelly
• Drill Pipe
• Drill Collars
• Heavy Wall Drill Pipe
• Bottomhole Assembly Tools

Drilling Fluids and the Circulating System

• Drilling Fluid Functions, Composition & Properties
• Drilling Rig Circulating System
• Drilling Fluid Components & Additives

Directional and Horizontal Drilling

• Deviation in Vertical Wells
• Directional Drilling Tools and Techniques

Drilling Problems and Drilling Optimization

• Drilling Rig Hydraulics
• Abnormal Pressure Environments
• Kick Detection & Control
• Stuck Pipe
• Fishing Operations
• Drilling Optimization

Cementing

• Cement Testing Procedures
• Cement Additives
• Primary Cementing Equipment
• Primary Cementing Operations

Drill Bits

• Bit Hydraulics

Prepare well for formation evaluation. Ensure that logging and testing operations proceed smoothly. Run and cement production casing. Evaluate primary cement job and need for remedial cementing operations. Prepare well for final completion.

Upon completion of this module, the participant should be able to:

• Prepare the well for open-hole logging operations and take steps to ensure that such operations proceed smoothly.
• Alert the wellsite geologist and service company logging engineer of hole conditions that may require modifications or special precautions in the logging program.
• Assist in planning and carrying out a drill stem test.
• Determine safe operating parameters for running a production casing string.
• Plan and carry out a simple single-stage primary cementing operation.
• Use temperature surveys to determine the top of cement in the casing/hole annulus.
• Outline the steps involved in preparing the well for final completion and releasing the drilling rig.

As you approach target depth at Adams 8, your concern now shifts from optimizing the drilling process to preparing the well for logging, testing and completion operations. Although you are not directly involved in planning the formation evaluation program, you are responsible for monitoring hole conditions, getting tools safely to bottom and in general ensuring that operations proceed according to plan. Once these operations are completed, you will focus on the crucial task of running and cementing the 7-inch [178 mm] production casing. At the conclusion of this assignment, the well should be ready for a workover rig to perforate the production casing, run tubing and turn the well over to the Production Department.

In order to successfully complete this assignment, you will need to complete the following Background Learning subtopics, or be familiar with the subject matter that they contain:

Wellheads, Flow Control Equipment and Flowlines

• Casing & Tubing Head Equipment

Directional and Horizontal Drilling

• Directional Drilling Tools and Techniques

Drilling Problems and Drilling Optimization

• Drilling Rig Hydraulics

Cementing

• Manufacture & Classification of Oilwell Cements
• Cement Testing Procedures
• Cement Additives
• Primary Cementing Equipment
• Primary Cementing Operations
• Squeeze Cementing
• Cement Plugs
• Evaluating/Testing the Cement Job
• Fluid Flow Properties & Mud Displacement

Perforating

• Perforating Gun Types
• Perforating & Production Performance
• Electric Wireline Perforating

Drillstem Testing

• Types of Drillstem Tests
• Tool String: Conventional DST (Open Hole)
• Tool String: Other DST Types
• Testing on Floating Vessels
• Pressure Recorders for DSTs
• Surface DST Equipment
• DST Design & Field Procedures
• DST Interpretation: General Aspects
• DST Interpretation: Qualitative Analysis
• DST Interpretation: Quantitative Analysis

Logging Equipment and Procedures

• Logging Systems
• Logging Procedures

Well Logging Tools and Techniques

• Resistivity Logs

Establish Inflow Performance Relationship (IPR) and determine flowing well potential. Use systems analysis approach to predict and optimize production.

Upon completion of this module, the participant should be able to

• Use production data to define a well's IPR and flow potential under current operating conditions.
• Predict changes in well potential resulting from declining reservoir pressures.
• Evaluate the effects of various operating parameters on flowing well performance.
• Design a single-well production system based on analysis of individual system components.
• Select the appropriate tubing and flowline diameters for optimizing well performance.
• Predict future production rates based on changing operating conditions.

Well TR-34 is a recently completed development well in the Main Body sands of the Firestone Field. You have just completed an extended production test of this flowing well in preparation for tying it into the field's main production facilities. In this assignment, you will treat this well as a single production system extending from the reservoir to the first-stage production separator. You will analyze the test results to determine the well's potential and the effect of various operating parameters on its performance. You will then use your analysis to establish an optimal production rate and size the tubing and surface flowline.

In order to successfully complete this assignment, you will need to complete the following Background Learning subtopics, or be familiar with the subject matter that they contain:

Fluid Flow and the Production System

• Production Systems
• Inflow Performance Relationship
• Vertical Lift Performance
• Flowing Well Performance

Determine need for artificial lift. Evaluate and design system.

Upon completion of this module, the participant should be able to

• Distinguish among the common methods of artificial lift and understand their advantages and limitations.
• Select the most appropriate artificial lift method for a given set of well and economic conditions.
• Perform basic surface and subsurface design calculations for gas lift and pump-assisted systems.
• Monitor artificial lift performance .

Artificial lift is a means of reducing the backpressure on a well so that it can be produced at some desired rate. This may be accomplished by reducing the density of the wellbore fluid column, as is done in gas lift, or by using a pump to physically displace the fluids to the surface. In this Assignment, you will consider both types of artificial lift as you evaluate three scenarios: (1) a flowing well that has experienced a significant decline in production rate as reservoir pressure has decreased, (2) a well that is to be incorporated into an existing gas lift system, and (3) the installation of an Electrical Submersible Pump (ESP) at a water source well. Although these scenarios do not cover all of the artificial lift systems and combinations of methods that are currently available, they will give you a good idea of the issues that you must consider in designing such a system.

In order to successfully complete this assignment, you will need to complete the following Background Learning subtopics, or be familiar with the subject matter that they contain:

Artificial Lift Methods (Superseded December 2006)

• ESP System Design
• ESP System Monitoring & Operation
• Other Subsurface Pump Systems

Artificial Lift Methods

• Gas Lift
• Reciprocating Rod Pump Systems
• Progressive Cavity Pump (PCP) Systems
• Hydraulic Pump Systems
• Electrical Submersible Pump (ESP) Systems
• Plunger Lift Systems

Diagnose production problems related to formation damage and recommend appropriate solutions.

Upon completion of this module, the participant should be able to

• Diagnose various types of formation damage and identify stimulation candidates.
• Design a matrix acid stimulation treatment based on specific well conditions and reservoir characteristics.
• Specify the materials, equipment and pumping schedule for a hydraulic fracturing procedure.
• Apply traditional and modern sand control methods to optimize well productivity

Well stimulation treatments, which are designed to restore or enhance well productivity, are of two basic types. Matrix treatments are performed at pressures that are below the formation fracture pressure; they are primarily designed to remove near-wellbore damage. Fracture treatments, on the other hand, are performed at pressures above the formation fracture pressure; they are designed to open up highly conductive flow paths between the reservoir and the wellbore, thereby bypassing near-wellbore damage and changing the flow patterns around the well.

Sand control technolgy is built around preventing loose sand and other unconsolidated formation solids from plugging the formation or entering the wellbore. As you will see in this assignment, stimulation and sand control technologies are in some ways closely related, and under certain circumstances, may even overlap.

In this assignment, you will carry out preliminary design work both for a matrix acid stimulation and a hydraulic fracture treatment, and will also select the appropriate sand control measures for a flowing production well. In each case, you will evaluate the nature and extent of the near-wellbore damage that has made stimulation and/or sand control necessary.

In order to successfully complete this assignment, you will need to complete the following Background Learning subtopics, or be familiar with the subject matter that they contain:

Basic Completion Design and Practices

• Completion Productivity

Acidizing and Other Chemical Treatments

• Acid Treating Solutions
• Additives in Acidizing Fluids
• Matrix Acidizing
• Fracture Acidizing
• Diverting Materials in Acidizing
• Wellbore Cleanout and Scale Removal
• Paraffins and Asphaltenes

Hydraulic Fracturing

• Hydraulic Fracturing Fundamentals
• Hydraulic Fracturing Fluids
• Proppant Agents
• Acid Fracturing
• Hydraulic Fracture Treatment Design & Execution
• Hydraulic Fracturing: Emerging Technologies

Sand Control

• Sand Production in Oil & Gas Wells
• Completion & Production Practices
• Liners & Screens
• Gravel Packing
• Frac-and-Pack Techniques
• Consolidation Techniques
• Sand Control in Wells Producing Heavy Oil

Identify workover candidates and outline procedures for accomplishing well objectives.

Upon completion of this module, the participant should be able to

• Evaluate well performance and identify workover or abandonment candidates.
• Plan safe workovers using the tools and methods appropriate to individual wells.
• Apply procedures and standards in accordance with recognized safe practices and regulatory requirements.

A review of the producing wells in the Adams portion of the Tremont Field has indicated that several wells need attention and may be workover candidates. In this assignment, you will evaluate conditions at these wells, take steps to troubleshoot these conditions, and recommend remedial action. You will also be getting ready to perforate the production casing in Adams 8, a newly drilled Sixth Zone producer.

In order to successfully complete this assignment, you will need to complete the following Background Learning subtopics, or be familiar with the subject matter that they contain:

Wireline Production Operations

• Wireline Surface Equipment
• Wireline Tool String, Basic Components
• Wireline-Operated Completion & Production Control Equipment
• Wireline Remedial Operations

Oilfield Safety

• Safe Work Practices

Basic Completion Design and Practices

• General Design Criteria
• Basic Downhole Configurations

Cementing

• Manufacture & Classification of Oilwell Cements
• Cement Additives
• Squeeze Cementing
• Cement Plugs
• Evaluating/Testing the Cement Job

Perforating

• Perforating Gun Types
• Perforating & Production Performance
• Electric Wireline Perforating
• Tubing-Conveyed Perforating

Fluid Flow and the Production System

• Flowing Well Performance

Completion Equipment

• Packers
• Downhole Completion Accessories
• Subsurface Safety Valves (SSSVs)

Generate production facilities requirements. Promote safe practices in production operations.

Upon completion of this module, the participant should be able to:

• Review surface flowing well conditions with the goal of optimizing production.
• Describe the basic layout of an upstream producing facility and the functions of its major components.
• Outline the general requirements for separating and treating produced oil as a basis for a detailed facility design.
• Plan and oversee routine field maintenance work, and maintain a safe operation through proper application of good work practices and the careful control of site activities.

The Sucre field's existing upstream surface facilities are designed for primary recovery, but that is about to change as preparations begin for a full-scale water injection project in The Upper/Middle Sands. As part of these preparations, you will address some of the general issues involved in modifying these facilities. You will also be involved in ongoing field operations; specifically, you will be responsible for safely completing repair and maintenance work on one of the field's main production separators.

In order to successfully complete this assignment, you will need to complete the following Background Learning subtopics, or be familiar with the subject matter that they contain:

Wellheads, Flow Control Equipment and Flowlines

• Valves, Fittings & Flanges
• Production Manifolds

Fluid Separation and Treatment

• Separation of Produced Fluids
• Treatment of Separation Oil

Oilfield Safety

• Emergency Prepareness
• Incident Reporting & Investigation
• Safety Hazards in Oil & Gas Production
• Safe Work Practices
• Safety & Control of Site Activities
• Fire Prevention & Control

Fluid Flow and the Production System

• Production Systems

Oil Systems and Equipment

• Two Phase Separators
• Three Phase Separators
• Oil Treaters

Gas Systems and Equipment

• Acid Gas Removal

Water Systems and Equipment

• Treating Oil from Produced Water
• Removing Solids and Dissolved Gases from Produced Water

Instrumentation

• Flow Measurement and Control