Fekete - Fekete F.a.s.t. Software Brochure 4u4g71

RESERVOIR ENGINEERING

Software & Services

TABLE OF CONTENTS ....................................................................................... 03 Information...................................................................... 04 Key s................................................................................ 04

SOFTWARE & CASE STUDIES Fekete Harmony™........................................................................ 05 F.A.S.T. DeclinePlus™................................................................... 06 F.A.S.T. RTA™............................................................................... 08 F.A.S.T. CBM™.............................................................................. 10 F.A.S.T. Evolution™....................................................................... 12 F.A.S.T. FieldNotes™.................................................................... 14 F.A.S.T. Piper™............................................................................. 16 F.A.S.T. VirtuWell™........................................................................ 18 F.A.S.T. WellTest™......................................................................... 20 SERVICES Geological Studies....................................................................... 22 Pipeline Optimization................................................................... 23 Production Optimization.............................................................. 24 Regulatory Applications............................................................... 25 Reserves Evaluation..................................................................... 26 Reservoir Engineering & Simulation............................................. 27 Unconventional Gas Studies........................................................ 28 Well Test & Production Data Analysis........................................... 29 Project Experience....................................................................... 30 Training......................................................................................... 31

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Fekete Associates Inc. is a consulting company based in Calgary, Alberta, Canada. We provide integrated reservoir management services and software to the oil and gas industry worldwide. Founded in 1973, the company has grown on the basis of its technical excellence and client service. Our client list includes over 1000 companies worldwide.

Our Staff Fekete currently has a full-time staff of over 170 engineers, geologists, technologists, programmers and personnel.

Our Software As an integral part of our petroleum engineering and geological consulting work, we develop software that incorporates the latest in technology. Our software is innovative, easy to use, and provides practical and advanced solutions for reservoir engineering and production optimization projects.

Our Services Fekete approaches every project with a dynamic, technical, and practical attitude. We remain on the leading edge of research in reservoir engineering and implement “best practices” into our software and services. This is reflected in the wide variety of projects undertaken over the years and has resulted in better reservoir management and production optimization for our clients. The professional quality of Fekete’s work is matched by our continuing service and technical .

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INFORMATION Calgary

Houston

Suite 212, 10777 Westheimer Rd. Houston, Texas, USA 77042

Suite 2000, 540-5th Avenue S.W. Calgary, Alberta, Canada T2P 0M2 Phone: 403.213.4200 (main) Toll Free: 1.800.625.2488 (North America only) Email: [email protected]

fekete.com

KEY S Louis Mattar, President Email: [email protected]

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Fekete Harmony™ is a software environment created by Fekete to host our Well Performance Analysis applications. Fekete Harmony™ includes tools for the preparation, editing and visualization of data which will be used in various analysis techniques, and summarizes the results in a comprehensive reporting tool. Fekete Harmony™ also allows the development of customized workflows that will reflect a company’s specific strategy or experience in reservoir evaluations. Fekete Harmony™ includes the following products: F.A.S.T. DeclinePlus™ F.A.S.T. RTA™ Products coming to Fekete Harmony™ in 2011 Q4: F.A.S.T. CBM™ F.A.S.T. VirtuWell™

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SOFTWARE

PRODUCTION ANALYSIS & RESERVES EVALUATION

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Streamline Your Reservoir Engineering Process in a Single Application

Production Analysis & Reserves Evaluation

Analyze Production Data: Analysis methods in F.A.S.T. DeclinePlus™ include traditional and tight gas/shale decline, type well decline, volumetrics, advanced material balance, water-oil-ratio (WOR) analysis, and ratio forecasting. Analysis methods can be dynamically linked to share common inputs and enforce consistent results. Advanced Workflows: Fekete Harmony™ contains enhanced plot creation and series manipulations, defined plot templates and analysis workflows. Templates and automated workflows can be easily loaded and set as default enabling the to save time and increase efficiency. Wells are sorted in defined, attributes-driven hierarchies that make analysis and reporting completely customizable.

Reserve Evaluation: Assign reserve classifications to well or group forecasts. Consolidate entity forecasts to group and hierarchy levels based on reserve classification or forecast name. Consolidations update dynamically with changes to individual well forecasts.

GIS: An interactive map allows for incorporation of geological interpretations. Wells can be selected and grouped through the GIS. Shapefiles and image files such as topographical maps, net pay, surface facilities, and land holdings are easily incorporated. New wells and undeveloped locations are created with a single click.

CASE STUDY

Objectives: • Identify appropriate analog wells for type well forecasting. • Create type well decline curve for use in undeveloped locations. . • Apply type well decline curve to wells with limited production history and adjust to well performance.

Background:

• 37 producing wells in area of interest, 2 with limited production history. • 10 planned well locations requiring forecast for proved plus probable undeveloped reserves.

Analysis: • Use Type Well decline to create average forecast for the area, EUR x Bcf. • Apply type well forecast to wells with limited history and well locations.

Results: • Type Well decline based on the average performance of wells. • Undeveloped locations added to GIS. • Type Well forecast applied to undeveloped locations and wells with limited production history. • Consolidations based on reserve types for economics.

Case Study

• Create consolidation for field total production and compare to consolidation without locations.

Evaluating Tight Gas Using Traditional Methods

• Tight gas play in Northeast B.C.

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SOFTWARE RATE TRANSIENT ANALYSIS

Estimate Fluid Volumes: F.A.S.T. RTA™ provides multiple independent techniques for estimating original oil and gas-in-place (OOIP/OGIP) and expected ultimate hydrocarbon recovery (EUR) without the need for shutting-in the well and production downtime.

Reservoir Characterization: Use a variety of advance decline analyses type curves and models in F.A.S.T. RTA™ to determine skin, permeability, drainage area, and fracture half-length.

Operating Diagnostics:

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Put Your Production Data to Work

Rate Transient Analysis

Monitor reservoir depletion performance to identify wellbore or reservoir related issues such as pressure (due to aquifer, geo-mechanical, etc.) or pressure loss (due to interference, liquid loading, etc.).

Unconventional Reservoir Module: The Unconventional Reservoir Module (URM) is a simple yet rigorous hybrid-technique (analytical and empirical) featuring multiple analysis methods used for the interpretation and forecasting of production from tight oil and gas wells.

Production Optimization: Generate a production forecast and conduct “what if” scenario analyses to assess the potential impact of changing the operating conditions at the wellhead: adding compression, drilling infill wells, stimulating the well, etc.

CASE STUDY

Objectives: • Identify the optimal drilling location for an infill well. • Determine if offset wells are interfering with the original producing well. • Estimate total reservoir OGIP. Background: • Conventional gas reservoir in western Canada. • Field had produced for one year. • Limited shut-in data but good flowing rate and pressure data. • Optimize production of producing wells. • Three wells in study: - Primary well came on at 1.6 MMcfd. - First offset came on at 2.0 MMcfd. - Second offset was marginal producer. Analysis:

- Identified ultimate recovery of ~ 1.4 Bcf. - Inconclusive about interference effects. • Advanced decline analysis methods (using flowing rate AND pressure data): - Estimated minimum reservoir OGIP of 4.8 Bcf. - Confirmed interference between original producing well and first offset well. - Defined drainage area and boundaries for each well.

• Provided justification to the planned infill drilling program. • Confirmed that one offset well was interfering with the original producing well. • Generated estimate of reservoir OGIP that was substantially higher than predicted by traditional decline analysis. • Identified optimal drilling location for new well.

Case Study

Results:

Where Should I Drill My Next Well?

• Traditional decline analysis (rate data only):

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SOFTWARE

COALBED METHANE RESERVOIR ANALYSIS

History matched data. Regions on the plot illustrate the liquid lifting/loading possibilities.

Analysis of Production Data: Use type curves and reservoir models to match the production data and flowing pressures. Use the matches to estimate properties such as permeability, skin, and drainage area and to diagnose problems such as liquid loading, interference and change in operating conditions. Production and Field Optimization:

Gas production forecast based on variable bottomhole flowing pressure.

Forecast well performance using variable bottomhole flowing pressure and skin. Evaluate the benefits of compression, stimulation, and infill drilling. Quickly import reservoir properties into F.A.S.T. Piper™ to design and optimize your gas gathering system.

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Practical Toolkit for CBM Engineering Needs

Coalbed Methane Reservoir Analysis

Reserve Estimation:

Likely span for gas and water rates obtained from Monte Carlo simulation.

Multiple analysis tools are available to estimate the original-gas-in-place (OGIP), expected ultimate recovery (EUR), and recovery factor. These include deterministic methods such as volumetrics, static and flowing material balance and traditional decline analyses as well as probabilistic risk analysis using Monte Carlo simulation. Modeling Capabilities:

(a) Model selection tool (b) A plan view of pressure propagation in a numerical horizontal well model.

Various models, analytical and numerical, can be utilized to characterize a reservoir. Apply single Vertical/Vertical Fracture/Horizontal numerical well models to history match the production or generate post-history forecast for multi-phase (Gas-Water) production. Apply single Vertical/ Vertical Fracture/ Horizontal/ Composite/ Multilayer well-reservoir models for single phase history match and production forecast. Multi-Layer Capabilities:

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Multiple layers of coal or sand can be included in a model. The model can then be used to generate a production forecast for each layer or history match the commingled production of a well completed and producing from several zones.

CASE STUDY

Two-phase production forecast for a multi-layer (2 coal & 1 sand) reservoir.

Objectives: • Forecast future production and reserves update. • Optimize production of producing wells. • Identify the infill drilling potential and devise development plan. • Build a gas gathering model that could be used for field optimization.

Background: History matching and post-historical data production forecast.

• Large CBM field in the USA, with complex reservoir behavior. • Large variation in reservoir properties. • Changing gas composition due to presence of CO2. • In excess of 25 years of production history. • Several hundred wells are tied into a complex pipeline network.

• History matched production data (gas rate, water rate, wellhead pressures) from each well. Use binary isotherms when fraction of CO2 in the produced stream becomes important.

• Generated production forecasts for gas, water, and CO2 fraction. • ed for unique CBM characteristics such as binary desorption and matrix shrinkage. • Built and calibrated a gas gathering model using the history match results.

Bubble map displaying well drainage area.

• The permeabilities obtained from history matching were found to be greater than 30 md in some areas and as low as 0.1 md in other areas. • Locations where drainage areas were less than the well spacing were identified for potential infill drilling. • Identified 100+ candidate wells for artificial lift.

Case Study

Results:

How Many More Wells Should We Drill?

Analysis:

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SOFTWARE

TIGHT & SHALE GAS DEVELOPMENT PLANNING

Determine Optimum Well Spacing: Answer the question “How many wells do I need to optimally produce this field?” by comparing and evaluating a wide range of development scenarios based on both recovery and profitability indicators. Test the sensitivity of results to uncertainty in various reservoir and economic input parameters.

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Make Better, Faster Field Planning Decisions

Tight & Shale Gas Development Planning

Schedule On-stream Dates for New Wells: Determine when new wells need to come on-stream to maintain a predetermined maximum field production rate. F.A.S.T. Evolution’s™ sophisticated analytical reservoir model predicts performance of new wells, properly ing for depletion and well placement.

Optimize Surface Capacity: Use F.A.S.T. Evolution™ to determine the most efficient usage of gathering system facilities in a “green field” development. Run multiple scenarios using different maximum field rates to find the most profitable results.

Evaluate Optimum Fracture Spacing in Horizontal Wells: Use F.A.S.T. Evolution™ to generate production and cash-flow forecasts for different complex completions, including multi-laterals and multi-stage fractures.

CASE STUDY

Figure 1: Recovery Factor Versus Number of Wells Drilled

Objectives:

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• How many wells should be drilled to achieve a total field recovery factor of at least 70%, over 20 years?

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• What is the most profitable well spacing scenario?

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• What is the optimum field production rate, given that infrastructure will be expensive (letting the wells flow unrestricted will be cost prohibitive)? • What is the optimum drilling schedule to achieve the desired field production rate?

Figure 2: NPV Versus Number of Wells Drilled 10000 9500 9000 8500

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• Operator X has acquired new acreage offsetting a large tight gas development.

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Analysis: Figure 3: NPV Plot Comparing Three qmax Scenarios Net Present Value versus Total Number of Wells

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Figure 4: Calculated Well Schedule for qmax = 5 MMscfd

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• Figure 3 suggests that the optimum field development scenario consists of drilling 13 wells with a maximum rate limitation of 5 MMscfd for the field. • Figure 4 shows the resulting well schedule.

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Results:

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• Operator X began with some basic reservoir, well and economic data, but little or no direction. Using F.A.S.T. Evolution™, we were able to quickly and systematically find a theoretically optimum development strategy for their undrilled acreage.

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Case Study

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New Tight Gas Field Development Study

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SOFTWARE DATA COLLECTION AND REPORTING

Ready for the Field: Monitor Post-Completion Flow Backs and Limited Production Tests.

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High Tech and Reliable Well Testing Software with 24 / 7

Data Collection and Reporting

• Select a customizable template to represent the type of test being conducted. • Production rates, volumes, and ratios are immediately calculated as data is entered. • Quickly generate detailed plots and reports for submission to client and regulatory agencies. • Calculate super compressibility using AGA 8 (detailed or simplified) or the Benedict-Webb-Rubin equation of state method. • Calculate returning frac gas (CO2, N2 and propane) from reservoir gas. • Separate fluid production into oil (stock tank equivalence), water and sediment. • Identify swabbing sequences and recoveries.

Real Time Data Acquisition: • Connect any surface or sub-surface instrumentation that s standard Modbus Protocol. • Set alarms to monitor tanks, separators, rates, etc., and automatically issue an email report. • Data plots and tables are updated instantaneously to detail current operating conditions. • Sample rates of one second during build-ups can provide valuable insight into the reservoir when used with F.A.S.T. WellTest™.

CASE STUDY

Objectives: CASE 1

• To determine the amount of injected gas recovered during the post-frac flow back. . Background:

Results: • The plot represents a comparison between the amount of N2 (blue), total gas (red), and the net reservoir gas (green) produced. The black line represents the total N2 injected. • By the end of the test, the amount of N2 that is returned from the formation is 1,473 mscf.

Objectives: • To determine the amount of frac liquid recovered during the post-frac swab operation.

Background: • Perforated the first zone and performed an initial frac using 200 bbl of fluid. • This was followed up 24 hours later with another frac using 940 bbl of fluid. • Perforated the second zone and performed an initial frac using 673 bbl of frac fluid.

Results: • The table illustrates a typical swab recovery template with the corresponding plot below. • During this swab operation, they recovered 880 bbl of 1,666 bbl leaving 786 bbl for the production testers.

Case Study

CASE 2

What is the Best Way to Record and Report Well Test Data?

• 1,600 mscf of nitrogen pumped into the well during the frac treatment.

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SOFTWARE GAS GATHERING SYSTEM ANALYSIS

Complete and Easy Field Development Planning: Quickly model existing and future gas gathering systems from the reservoir to sales. Build your gathering system with on-screen drag and drop techniques and locate within a GIS interface. Underlie shapefiles and images to view culture and topography. Define deliverability, pipelines and compression. Forecast future field optimization scenarios.

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Model Gas Flow from the Reservoir to the Delivery Point

Gas Gathering System Analysis

Production Optimization: Various diagnostics allow for easy identification of: • Bottlenecks within the gathering system. • Data errors. • Liquid load-up in the wellbore. • Uplift potential. • Build a gas gathering model that could be used for field optimization. Production Forecasting and Development Justification: Determine wellbore, pipeline and compression requirements. Run “what if” scenarios to assess the impact of drilling infill wells, adding compression and adding pipeline capacity. Determine if proposed developments are economic based on F.A.S.T. Piper™ forecasts. Import F.A.S.T. RTA™ and F.A.S.T. CBM™ Models: Investigate the field wide response of your calibrated reservoir characterization. Quantify flush production on a daily or monthly basis, investigate the extent of the back-out of existing wells and identify potential problems due to liquid loading. Modify reservoir parameters to evaluate the impact of re-completions and schedule those changes to reflect current timelines.

CASE STUDY

Objectives: • Determine production improvement from debottlenecking gathering system.

Background: • 90 wells on production. • Psuction = 170 psia. • Wellhead pressures range 200 psia - 500 psia. • Total gas rate 16.0 MMscfd.

Analysis: • Generated a model with additional 14 miles of 8” pipeline to evaluate the Pressure Distribution Map and the Frictional Pressure Loss Map. • Increased compressor capacity to for additional gas volumes.

Results: • Reduced suction pressure by 40 psia. • Reduced wellhead pressure by as much as 300 psia.

Other Studies: • 11 other gathering systems are modeled and updated on a regular basis for this company.

Case Study

• Increased gas rate by 3.0 MMscfd.

Evaluate Upside Potential in Debottlenecking

• Mainline bottleneck.

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SOFTWARE WELLBORE OPTIMIZATION

Convert Between Wellhead & Bottomhole Pressure: Calculate pressure drop in the wellbore to estimate bottomhole or wellhead pressure for: • Single or Multiphase (gas, water, oil, condensate) flow, including hydrates detection. • Vertical, horizontal, or deviated wells.

• Flow through casing or annulus and / or tubing. • Use static or production / injection pressures. Model Well Deliverability & Liquid Loading: Use various sources to generate past, current, and future IPR curves. Model different operating conditions for oil and gas. • Liquid loading. • Compression. • Coiled tubing / velocity strings.

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Efficient Flow from Sandface to Surface

Wellbore Optimization

• Soaping. • Alternate flow paths. Determine expected rates for various scenarios. Wellbore Diagram: Visually construct detailed schematics for complex wellbores. • Enter TVD and MD. • Single or multiple perforations. • Model tapered casing and / or tubing. Choke Analysis: Find the most appropriate choke size to reach a certain flow rate or pressure. • Enter choke size and set depth. • Single or multiphase (gas, water, oil, condensate) flow. • Full flow rate range.

Objectives: • Identify if and why the well is liquid loading. • Evaluate the effect of coiled tubing.

Background: • Vertical gas well in east Texas. • Well has now produced for 4 months. • 2-7/8” Tubing to 11,200 ft. • 5-1/2” Casing to 11,540 ft. • Perfs from 11,150 ft to 11,237 ft. • No bottomhole flowing pressures measured.

- Initial PR = 6,600 psia. Current PR = 5,840 psia. - Initial production was 1.20 MMscfd at 320 psia WH pressure. WGR = 15 bbl/MMscf. - Current gas rate is approximately 0.65 MMscfd and intermittent. Analysis: SF / WH AOF Module: • Initial surface rate and pressure is used to create a sandface IPR curve. Gas AOF / TPC Module: • Maintaining a wellhead pressure of 320 psia and 15 bbl/d of water requires a rate of 1.09 MMscfd to lift liquids. • At a reservoir pressure of 6,250 psia, liquid loading occurred. • Current PR = 5,800 psia.

Results: • 1-1/2” coiled tubing was installed and the well unloaded as expected. New wells in the area have since been completed with 1-1/2” coiled tubing from initial production.

This Well is Loaded Up. What Should I Do?

• Well history:

Case Study

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CASE STUDY

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SOFTWARE

ADVANCED PRESSURE TRANSIENT ANALYSIS

Analyze Build-Up and Drawdown Data: Load and plot data with easy-to-use import and filtering tools. Built-in wizards guide the from data input through analysis, modeling and forecasting. “Controlled” tests or “un-planned” build-ups on producing wells are easily analyzed using the flexible data management feature.

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Everyday Well Test Data Interpretation Tool

Advanced Pressure Transient Analysis

Design and Analyze Perforation Inflow / Injection Tests (PITA) to Establish Initial Reservoir Pressure and Permeability: Simulate the pressure build-up or fall-off response expected after perforating. Establish the minimum shut-in time required to quantify the reservoir pressure and estimate permeability. Analyze the test data using the new PITA analysis option developed by Fekete.

Analyze Mini-Frac Tests to Estimate Reservoir Pressure and Permeability: Pressure fall-off data from mini-frac tests (after frac-closure) can be analyzed using the new PITA injection analysis option to estimate reservoir pressure and permeability.

Predict Deliverability Performance: Using results determined from pre-frac tests, predict the deliverability performance for different frac properties to establish optimum frac design.

CASE STUDY

Objectives: • To establish the reservoir flow characteristics and obtain a reasonable production forecast.

• Shallow gas well with low pressure. • A 4-point modified isochronal test was conducted to establish the deliverability potential. • The well looked great at surface with the 16 hour extended flow stable at 1.1 MMscfd.

Analysis: • The pressure recorders were retrieved after a 2 week build-up and revealed a much different story. • Even without detailed analysis, pressure loss is evident and raises suspicions of a very limited reservoir. • History matching indicates: - a zone of good permeability that extends to a radius of about 525 ft from the well (20 acres). - a tight zone that extends to a radius of about 1200 ft from the well (105 acres). - an OGIP of 0.94 Bcf.

• Indication of small reservoir size and GIP seriously impacted tie-in decision and development plans for future wells. • The client can use this forecast to determine the project economics of tie-in and when to install compression.

Case Study

Results:

Why Do I Need to Test a Well Exhibiting Stable Flow on Cleanup?

Background:

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SERVICES GEOLOGICAL STUDIES

Fekete’s geoscientists have evaluated prospects around the world. The strength of our expertise is the interdisciplinary co-operation between Fekete’s geological, petrophysical, geophysical, and reservoir engineering staff, and the integration of their results to arrive at a practical and technically rigorous reservoir interpretation. The geoscience team’s interpretation of oil and gas reservoirs incorporates all pertinent stratigraphic, structural, and petrophysical analyses. Gross and net pay analyses and the areal extent of reservoirs are determined through detailed correlations of hydrocarbon zones and surrounding strata. The stratigraphy, lithology, depositional environment and subsurface structure are also assessed. Also, Fekete determines reservoir parameters from petrophysical logs, core analyses, drillstem tests and well completion information. Mapping and modeling of reservoirs is completed utilizing all available information for a study area. Fekete’s geological professionals provide an array of services for both domestic and international projects. These include: Basin Analysis: • Sequence stratigraphic analysis. • Paleo-environmental interpretation. • Resource mapping and assessments. • Exploration prospect generation and risk assessment. • Petroleum geochemistry. Reservoir Management: • Basin analysis and modeling for production optimization (including EOR – secondary & tertiary recovery). • Basin and regional studies for hydrocarbon potential. • Gas storage evaluations. • Property evaluations and resource assessments. • Regulatory applications. • Expert witness. Petrophysical / Core Evaluations: • Petrophysical evaluations. • Sequence stratigraphy – stratigraphic and sedimentological interpretation. • Detailed core descriptions. • Depositional facies analysis. 3D Reservoir Modeling: • Digitizing and volumetrics. • Reservoir characterization and subsurface mapping. • Reservoir simulation – structural and facies modeling and upscaling.

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SERVICES

PIPELINE GEOLOGICAL OPTIMIZATION STUDIES

Fekete’s abilities in gas gathering system optimization have been recognized as a truly unique and valuable service to the oil and gas industry. Using our F.A.S.T. Piper™ software, Fekete’s engineers are able to build a model of a gas gathering system that includes the surface gathering system, wellbores, and reservoirs. On the surface, F.A.S.T. Piper™ has the capability to model complex pipeline systems with actual sizes, routes, and elevation changes along with various facilities such as compressors, separators, off-takes, and intakes. Wellbore modeling allows the engineer to analyze wellhead and sandface deliverability and determine if and when a well is capable of lifting liquids to surface. In addition, tank-type (volumetric depletion), transient, water-drive, connected, geopressured or coalbed methane reservoirs may be incorporated into a F.A.S.T. Piper™ model. After building the model, Fekete personnel can conduct a field tour to obtain accurate flowing pressures and investigate compressor operations. This provides a snapshot of system performance to which the model is calibrated in order to represent actual field conditions. After calibration, future production forecasts can be generated with “what if” scenarios, including compressor changes, new well tie-ins, debottlenecking, accelerated recovery, and more. From multiple zone / multiple pressured systems in Alberta, coalbed methane systems in Wyoming, high pressure gas in Pakistan, to tight gas in Australia, our engineers have accumulated a vast range of experience and valuable insight. Many clients have chosen Fekete’s expertise because our recommendations generate immediate production increases at minimal cost and risk. Fekete’s engineers can build a model of a gas gathering system including: • Actual pipeline sizes, routes, and elevation changes. • Well deliverabilities. • Multiple zones with different pressures, reserves, and depletion. • Multiple delivery points. • Different gas compositions. • Rigorous model based production forecasting. • Aquifer or communicating reservoir modeling for material balance. • Compositional tracking for product allocation. • Historical production matches and overlays.

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SERVICES GEOLOGICAL STUDIES PRODUCTION OPTIMIZATION

Fekete’s Production Optimization group investigates and identifies upside reserve and production potential which can then be developed and added to your booked reserves. We have developed a comprehensive Opportunity Banking Database process which incorporates geological, reservoir, completion, production, and economic analyses into a comprehensive summary of your assets. Specifically, the process includes petrophysical evaluation of byed pay including offset analogies and recommended perforation intervals, testing programming, remedial workover programming for under-performing wells, assessment of optimal well spacing, abandonment liabilities, and project economics. All projects are managed in a knowledgeable database with additional information appended as operations advance. Projects are prioritized so that they can be instantly reactivated if oil or gas prices jump or new facilities are built nearby. Project tracking is easy and ideas are never lost with staff turnover. We have many years of experience and an excellent track record. Clients have realized millions of dollars of upside production based on our results. Another specialized service is Wellbore Optimization using Fekete’s F.A.S.T. VirtuWell™ software. IPR’s, AOF curves, liquid loading, stripper compressors, choke sizing, and velocity strings are modeled to determine the best downhole tubular configuration. In addition, Fekete’s Production Optimization group enjoys working on unusual projects that do not fit conventional categories. These include: • Acid gas disposal. • Frac optimization. • Expert witness testimony. • Audit of field operations for “best practices” and cost effectiveness. Ultimately, our goal is to maximize recovery by optimizing production and operations of your oil and gas assets. We investigate all aspects of the problem by drawing upon Fekete’s multi-disciplinary expertise. In the end, we bring forward solutions that either add value or cut costs.

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SERVICES

REGULATORY GEOLOGICAL APPLICATIONS STUDIES

Fekete assists oil and gas companies in their reservoir management plans by pre-planning and obtaining the necessary regulatory approvals in British Columbia, Alberta and Saskatchewan. We have completed and received approval for thousands of applications. Our applications are technically complete, accurate, and ensure a favorable evaluation by the regulatory authorities. We can also provide expert witness testimony at government and court hearings. By using Fekete to handle your regulatory applications, your staff can concentrate on their core responsibilities. The applications we routinely prepare are: • Downspacing. • Holdings. • Gas production in oil sands areas. • Commingled production. • Good production practice (GPP). • Concurrent production. • Gas-oil ratio penalty relief. • WGR and ECF exemptions. • Pool delineation. • Enhanced recovery (waterflood). • Water disposal. • Acid gas disposal. • Metering waivers. • Allowable calculations. • 0-38 submissions. • Primary schemes for heavy oil. • CEE / CDE new pool classification.

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SERVICES RESERVES EVALUATION

Fekete’s qualified reserve and resource evaluators identify and address key technical and economic issues. We use our considerable in-house experience, specialized expertise and the full spectrum of Fekete’s software to understand your reservoirs, to model and forecast production, and to provide reserve estimates with confidence. We prepare professional NI 51-101 and SEC compliant reserve reports for Canadian and United States regulators. We conduct, appraise, and audit reserves for a variety of purposes including: • Annual corporate reserve evaluations. • Individual property reports for acquisition, divestment, and mergers. • Audit of company reserves to satisfy banking requirements. • Fair market value estate evaluations. • Submissions to regulatory authorities regarding issues that require economic evaluations (i.e. otherwise flared solution gas holidays). • Assessments of prospective undeveloped lands. • Reserve certification for international / foreign clients. As we conduct our diligent review of your wells and properties, we make recommendations on reservoir management issues such as: • Increasing well density to maximize recovery. • Providing alternative pipeline / compressor routes to alleviate deliverability restrictions. • Enhanced recovery. • Monitoring well performance (flowing pressures and rates). • Conducting a pressure build-up test to determine well damage or for pool delineation. • Integrating seismic and geological models with our reservoir interpretations. Our group’s most important assets are our people, our reputation, and our relationships with our clients, the financial community, and the multitude of stakeholders who rely on a fair and independent reserve report.

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SERVICES

RESERVOIR ENGINEERING & SIMULATION

Fekete provides an integrated team of reservoir engineers, geologists, geophysicists, petrophysicists, production engineers, simulation engineers and computer specialists for detailed reservoir studies. We assemble the team consistent with the objective of the project, whether that is reservoir development and optimization, or improved reservoir characterization. Past projects include: • Reservoir Development and Optimization: such as WAG, CO2-EOR, thermal recovery, and waterflood design and optimization. • CO2 Sequestration and Acid Gas Disposal: such as reservoir engineering and modeling of CO2 storage aquifers in the Middle East and in Alberta as well as post-mortems on five acid gas disposal projects that have either unexpectedly pressured up or experienced unexpected acid gas breakthrough. • Reservoir Characterization: such as multi-well interference analysis for characterization of the size and permeability of “top water” and “lean zones” in SAGD operations, or connectivity between gas storage pools. • Experimental Schemes: such as natural-gas hydrate reservoirs and SO2 disposal. All simulation projects commence with a detailed review of data quality and analysis of the effect of data uncertainty on results. Preparation of the dynamic pressure and production data involves a screening process that uses practical oilfield experience. For example, completion reports are diligently reviewed for fracture effectiveness, perforation timing, injector/producer pair behavior, and more. More often than not, basic reservoir engineering techniques are then used to gain an understanding of the reservoir behavior, and prepare the simulation engineer for challenges during history matching and reasons for such challenges. For large reservoirs, Fekete’s geological, petrophysical, geophysical and reservoir engineering staff work in an integrated and interactive team. The geoscience team is responsible for building the static model that honors the depositional environment, and integrates independent stratigraphic, structural, and petrophysical analyses. Simulation proceeds only after scoping analyses determine that the integrated reservoir characterization model is representative of the reservoir, that it will generate trustworthy results, and that it is economically justified. Uncertainty assessment is included in the workflow, when necessary through the use of assisted history matching tools. After history matching, multiple realizations are run to investigate the full range of possible outcomes. We meet your objectives, whether it is to optimize the production and development strategy, or to improve reservoir characterization.

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SERVICES UNCONVENTIONAL GAS STUDIES

Fekete helps clients engaged in coalbed methane (CBM) and shale development to optimize production from new or existing wells. In the past few years, Fekete has been involved in a number of unconventional gas projects including: • Undertaking industry funded initiatives to study shale gas. • Reserve estimation of tight gas. • Analysis of production data and production forecast for Coalbed Methane reservoirs (including Horseshoe Canyon coal, Mannville coal, San Juan Basin, Black Warrior Basin, Drunkard Wash, …). • Analysis of production data and production forecast for shale gas reservoirs (Appalachian, Barnett, Haynesville, Montney). • Reserve evaluation of CBM, tight gas and shale gas reservoirs. • Provide evidence and engineering for regulatory applications such as downspacing. • Production optimization of new or mature CBM wells. • Preparing engineering reports to determine a CBM-specific development strategy. Fekete’s Unconventional Gas group has completed a variety of coalbed methane studies with some consisting of more than 1,000 wells. They include the high pressure, high gas content coals in the San Juan Basin, multi-zone coals of the Black Warrior Basin, dry Horseshoe Canyon and wet Mannville coals in Alberta, and Bowen Basin coals in Australia. Our completed projects include: • Viability of developing new CBM resources. • Optimal infill well spacing for development of existing fields. • Gas production forecasts and estimation of de-watering periods. • Reserve evaluation using volumetrics, traditional decline, static and flowing material balance and history matching. • Field development strategy. • CBM gathering system optimization using F.A.S.T. Piper™. Using the required engineering tools from simple single well tank-type models to complex multi-well gridded numerical models, Fekete engineers address complexities that arise in the analysis of unconventional gas reservoirs and generate reliable production forecasts. The complexities include but are not limited to gas desorption, diffusion, dual porosity reservoirs, undersaturated/saturated CBM reservoirs and reservoirs consisting of multiple layers of coal and sand.

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SERVICES

WELL TEST & PRODUCTION DATA ANALYSIS

At Fekete, we approach our business with a dynamic, technical and practical attitude. We have seen significant client value in combining our well test (Pressure Transient) and advanced decline (Rate Transient) analysis services under one common umbrella called Well Test & Production Data Analysis. Results obtained from combining both services allow a greater understanding of the reservoir, completion efficiency and optimization potential. Our expertise is further strengthened by our interdisciplinary co-operation between these services and with Fekete’s geological, petrophysical, geophysical and reservoir engineering professionals. PROJECTS: Well Test Analysis • Design and analysis of various tests (flow & buildup, injection & falloff, DST, perforation inflow, minifrac tests) to determine critical reservoir properties such as reservoir pressure, permeability, skin and fracture properties. • Estimate distances to reservoir boundaries and / or heterogeneities and establish reservoir volume. • Predict deliverability potential at various flowing conditions. • Recommend potential stimulation (for damaged wells) or optimization candidates (utilizing tubing performance curves and liquid lift calculations). • On-site supervision and software training. Advanced Decline Analysis • Accurate determination of in-place volumes. • Reservoir characterization (permeability, skin, fracture half-length). • Diagnose changing skin or permeability conditions. • Monitor well performance in competitive drainage situations. • Monitor productivity to ensure proper production allocation. • Determination of optimal well spacing and recoveries from infill drilling. • Providing drainage areas for regulatory downspacing applications. • Proof of “tight gas” for government tax credits.

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PROJECT EXPERIENCE Fekete has conducted projects in the following geographical areas: Canada: Alberta, British Columbia, Manitoba, New Brunswick, Newfoundland, North West Territories, Nova Scotia, Ontario, Saskatchewan, Yukon Territory

Africa/Middle East: Algeria, Egypt, Equatorial Guinea, Jordan, Libya, Iran, Qatar, Saudi Arabia, Senegal, Tanzania, Tunisia, United Arab Emirates, Yemen

USA: Alaska, California, Colorado, Indiana, Kansas, Kentucky, Louisiana, New Mexico, Michigan, Mississippi, Montana, North Dakota, Ohio, Oklahoma, South Dakota, Texas, Virginia, Wyoming

Europe: Austria, , Ireland, Italy, Kazakhstan, Netherlands, North Sea, Spain, Turkey

South America / Caribbean: Argentina, Bolivia, Colombia, Cuba, Ecuador, Peru, Trinidad, Venezuela

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Australasia: Australia, Bangladesh, China, India, Mongolia, Pakistan, Papua New Guinea, Philippines

TRAINING Fekete regularly teaches F.A.S.T.™ Software and Petroleum Engineering courses. Our instructors bring the best of advanced research and practical experience into the classroom. Students gain immediate, real-world skills that are applicable in their daily job. Completing a course from us will help expedite your learning and enable you to better solve your reservoir or production optimization problems. A Fekete course gives you immediate access, not only to our experts who use the software daily, but to technical advice on projects that you may currently be working on. Our courses provide an environment in which you can practice with case study material and sample files taken from actual studies conducted by Fekete. This gives you the confidence to apply techniques covered in the course immediately after you return to your job.

F.A.S.T. Software Courses: Fekete Harmony™ | F.A.S.T. DeclinePlus™, F.A.S.T. CBM™, F.A.S.T. FieldNotes™, F.A.S.T. Piper™, F.A.S.T. RTA™, F.A.S.T. VirtuWell™, F.A.S.T. WellTest™, Unconventional Gas Field Development using F.A.S.T. RTA™ and F.A.S.T. Piper™, Unconventional Pressure Transient Analysis in F.A.S.T. WellTest™ and Unconventional Rate Transient Analysis in F.A.S.T. RTA™

Petroleum Engineering Courses: Well Test Interpretation, Modern Production Data Analysis for Unconventional Reservoirs, Gas Deliverability Forecasting, Oil and Gas Well Spacing in Alberta

Additional Training: In addition to our regularly scheduled courses, Fekete has developed a number of Lunch & Learn presentations and In-House Training courses to meet your needs. Please our course coordinator at [email protected] to learn more about the course offerings provided by Fekete.

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FEKETE ASSOCIATES INC. Suite 2000, 540 - 5th Avenue SW | Calgary, Alberta | Canada | T2P 0M2 403.213.4200 | 1.800.625.2488 (North America only) | [email protected] | fekete.com

Copyright © 2011 Fekete Associates Inc. Printed in Canada. All logos and trademarks are the ed property of Fekete Associates Inc.

COALBED METHANE RESERVOIR ANALYSIS

MAIN FEATURES Isotherm / Volumetrics:

Type Curves for CBM:

Visually compare measured gas content of coal to the Langmuir Isotherm. Generate volumetric estimates of the recovery factor and recoverable reserves based on abandonment pressure or abandonment CO2 fraction. Calculate free, adsorbed and total gas-in-place.

Use Agarwal-Gardner Rate-Time type curve developed for dry coal to estimate gas-in-place as well as permeability and skin.

Analytical Models:

Monitor the fraction of CO2 in the produced gas by modeling the binary mixture of CH4 and CO2 using Extended Langmuir Isotherm.

Use analytical models to generate single-phase production forecast, history-match production or confirm results of other models. The available well/reservoir models includes fracture, vertical, horizontal, composite, multi-layer, horizontal multi-frac and multi-frac composite..

History Matching:

Matrix Shrinkage:

Import historical production data and match it to determine reservoir parameters (permeability, skin, drainage area, and porosity).

Invoke the matrix shrinkage option to model stress-dependent permeability of coal. Utilize different matrix shrinkage correlations for forecasting or history matching. Generate permeability vs. pressure plots for visual confirmation of correlations.

Binary Langmuir Isotherm:

Material Balance: Estimate original-gas-in-place using static material balance (including King, Seidle and Jensen & Smith methods) or flowing material balance (for dry coal).

Well Monitoring:

Deliverability Forecasting:

Multi-Layer Modeling:

Forecast gas and water rates, as well as average reservoir pressure and water saturation based on constant or variable flowing pressure and fluid levels. Use the multi-well option to quickly determine optimal drill spacing for play areas.

Numerical Models:

Use the well monitoring option to closely monitor the key factors affecting the production of new wells. Use the multi-layer functionality to history match the production or generate forecast for a well perforated into multi zones of coal and sand.

Risk Analysis:

Generate forecasts or history match production data using the numerical models available for single fracture, vertical or horizontal well configuration.

Perform Risk Analysis using Monte Carlo simulation to investigate the impact of uncertainty in reservoir/well parameters on the gas-in-place, EUR and gas and water production and find out the likely outcomes.

Data Diagnostics:

F.A.S.T. Piper™ Integration:

This feature shows a customizable collection of plots designed to quickly show data inconsistencies or operational issues in a producing well.

Analyze your CBM wells using F.A.S.T. CBM™. Import the results in F.A.S.T. Piper™ to forecast multiple wells & optimize tie-in locations, pipeline capacity and compression.

Sample plots generated from F.A.S.T. CBM™

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PRODUCTION DATA ANALYSIS & RESERVES EVALUATION

MAIN FEATURES Type Wells and Analog Performance:

Water-Oil-Ratio (WOR) Analysis:

Normalize analog well production to create a Type Well performance profile. Use the clipboard functionality to easily apply profiles to wells with little or no historical production.

Analyze oil reservoir performance using WOR, WOR+1, or water cut diagnostics. Generate oil and water rate forecasts based on constant or variable total fluid rate.

Advanced Workflows: Create analyses that can be independent or can be linked to enforce consistency in results. Develop defined plot templates with automatically generated analyses. Re-organize the data hierarchy on-the-fly to analyze groups based on an extensive list of parameters. Incorporate F.A.S.T. RTA™ into the workflow and compare results from traditional and advanced methods on the same plots.

Consolidations: Consolidate entity forecasts to group and hierarchy levels based on reserve classification or forecast name. Consolidations update dynamically with changes to well forecasts.

Forecasts Worksheet: Easily create by-product forecasts using constant or variable ratios. View, copy/paste or export entity forecasts for easy transition into economic software.

Tight Gas / Shale Decline: Exclusive to F.A.S.T. DeclinePlus™, a more rigorous method to match production decline from transient to boundary dominated flow. The transition time can be directly input or calculated based on estimates of permeability and drainage area.

Traditional Analysis Methods: Perform Arps’ decline analysis using advanced best fit options, multiple segments, and unique line manipulations. Conduct oil and gas volumetric calculations based on detailed reservoir parameters or mapped hydrocarbon pore volumes. Perform gas or oil material balance on single wells or reservoir groups using volumetric, geo-pressured, connected reservoir, or water drive gas models and volumetric, volatile oil, or geo-mechanical oil models.

Sample plots generated from F.A.S.T. DeclinePlus™

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TIGHT & SHALE GAS DEVELOPMENT PLANNING

MAIN FEATURES Determine Optimum Well Spacing:

Optimize Surface Capacity:

Determine how many wells are needed to optimally produce a field by comparing and evaluating a wide range of development scenarios based on recovery and profitability indicators. Test the sensitivity of results to uncertainty in various reservoir and economic input parameters.

Determine the most efficient usage of gathering system facilities in a “green field” development. Run multiple scenarios using different maximum field rates to find the most profitable results.

Net Present Value versus Total Number of Wells

Discounted NPV (M$)

Discounted NPV (M$)

Net Present Value versus Total Number of Wells

Total Number of Wells

Total Number of Wells

Schedule On-stream Dates for New Wells: Determine when new wells need to come on-stream to maintain a predetermined maximum field production rate. F.A.S.T. Evolution™’s sophisticated analytical reservoir model predicts performance of new wells, properly ing for depletion and well placement.

Evaluate Optimum Fracture Spacing in Horizontal Wells: Use F.A.S.T. Evolution™ to generate production and cash-flow forecasts for complex completions, including multi-laterals and multi-stage fractures. Forecast Rates

Field Production (MMscfd)

Rate Forecasst 1 (MMscfd)

Forecast 2 - Field Forecast: Stacked Production Rates

Time (month)

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Time Forecast 1 (month)

DATA COLLECTION AND REPORTING

MAIN FEATURES

Test Data Results:

Monitor Recovered Fluids and Frac Gases:

View test results at a glance with superb graphical presentation and detailed tabular outputs. Monitor key location for possible hydrating or liquid loading conditions.

Configure gas meters to monitor the amount of frac gases (CO2, N2, C3) and reservoir gases being recovered. Monitor the percent of load fluid (oil, water, mixed) recovered.

Gas and Fluid Meter Calculations: Gas rates are calculated using AGA 3, AGA 7 and AGA 8 specifications. Oil rate calculations use ASTM 1250D, AGA 7 and different oil correlations such as Standing and Vasquez & Beggs to determine GOR2 and liberated gas.

Manual or Real Time Data Gathering: Electronically gather production test data in “real time” from the wellhead, test equipment & downhole gauges using the ModBus Protocol. Alarm on critical maximum or minimum conditions. Import CSV or other ASCII file formats.

Test Data Transfer: Transfer production test data to pressure transient analysis software (F.A.S.T. WellTest™).

PAS Requirements: Meets Energy Resources Conservation Board (ERCB) Pressure ASCII Standard (PAS) requirements for electronic production test data submission in Alberta, Canada.

FieldNotes Viewer (free): View and print reports from F.A.S.T. FieldNotes™ and ERCB PAS files.

Sample plots and tables generated from F.A.S.T. FieldNotes™

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GAS GATHERING SYSTEM ANALYSIS

MAIN FEATURES Integrated Asset Modeling:

Compression & Pipeline Loops:

Use F.A.S.T. PiperTM to identify bottlenecks and operational problems with existing and proposed systems. Incorporate all aspects of your gathering system, including the reservoir, surface equipment and pipelines, to forecast production and compare optimization scenarios.

Models positive displacement compressors such as reciprocating and rotary screw configurations. Capable of modeling capacity curves or horsepower limits. Ideal for choosing optimum compressor locations. Model pipeline loops and flow loops explicitly.

Well Deliverability:

Project Manager (Time-Based Configurations):

Model deliverability at the wellhead or the sandface. Generate IPR curves from the wellhead and sandface to determine potential for production uplift. s conventional AOF methods as well as transient and coalbed methane deliverability.

Diagnostics: Analyze outputs by means of onscreen displays, bubble maps and various data plots and exports. Use pressure-based bubble maps to quickly identify high back pressure areas. Use velocity and friction based link maps to identify bottlenecks. Use uplift and drawdown bubble maps to identify wells with significant untapped potential. Visualize the impact on field pressure when incorporating development changes such as a proposed drilling program, additional compression, or new pipeline loops.

Economics: Evaluate the economics of a Piper scenario. for the capital costs of adding new wells ,facilities and pipelines. Model the fixed and variable costs of operating your system throughout the fields life. Adjust for inflation and set a discount rate. Specify a price deck based on either volume or energy content pricing. Evaluate individual wells or the system as a whole based on its net present value and cash flow.

Make changes to a gathering system in the future to predict the effects of adding new wells, looping pipelines, and adding compression.

F.A.S.T. RTATM Integration: New in February, 2010, import horizontal, fracture, composite or radial RTA analytical models. Forecast forward your RTA analytical well model under the constraints of your surface system, or run field studies to address the impact of field wide compression, looping and other optimization scenarios.

Production Forecasting: Combine deliverability with various reservoir models to forecast future production. Reservoir models include conventional volumetric (Tank-type), transient, water-drive, connected, geo-pressured and coalbed methane.

GIS Mapping Tool: Quickly construct proposed and existing gas gathering systems using geodetic location imports and/or on-screen editing tools. Underlay shapefiles and image files to facilitate construction to real world extents and insure that nodal connections match the field.

Screen shots generated from F.A.S.T. Piper™

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RATE TRANSIENT ANALYSIS

MAIN FEATURES Fetkovich Type Curves:

Specialized Analysis:

Analyze transient and boundary-dominated flow. Combines rate and cumulative type curves. Estimates EUR as well as skin and permeability.

A diagnostic tool to determine permeability, skin, and fracture half-length from the transient part of the data.

Flowing Material Balance:

Blasingame: Type curves for analyzing variable rate/variable pressure systems. Vertical, horizontal, fractured, and water-drive reservoirs. Estimates original fluid-in-place, permeability, skin, and fracture half-length.

Agarwal-Gardner: Includes raw and smoothed data derivative plots. Vertical, fractured, and water-drive reservoirs. Estimates original fluid-inplace, permeability, skin, and fracture half-length.

Converts flowing pressures to corresponding average reservoir pressure and calculates fluid-in-place using material balance.

Unconventional Gas Analysis Links square root-time plot and flowing material balance plot for analyzing tight/shale gas data. Estimates EUR and stimulation effectiveness.

Analytical and Numerical Models:

Well test-style type curve analysis with integration for data smoothing. Estimates original fluid-in-place, permeability, skin, and fracture half-length.

Analytically model vertical/horizontal wells, hydraulic fractures, multi-layers, composite, horizontal wells with multiple fractures, horizontal wells with multiple fractures-composite and water drives. Numerically model oil above and below the bubble point and gas-oil-water in vertical/horizontal wells and hydraulic fractures.

Wattenbarger:

Data Diagnostics:

Type curves for analyzing linear flow. Estimates original fluid-inplace, permeability, and fracture half-length.

Guides to identify problems with data quality BEFORE doing analysis.

Normalized Pressure Integral:

Sample plots generated from F.A.S.T. RTA™

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WELLBORE OPTIMIZATION

MAIN FEATURES Wellbore / Sandface Deliverability:

Plunger Lift:

Evaluate both sandface and wellhead deliverability curves for gas wells producing water and/or condensate. Determine sandface deliverability from sandface or wellhead test data.

Model gas wells lifting water and/or condensate on plunger lift. Evaluate the feasibility of a planned plunger lift installation for a well which is currently flowing but loading up. Improve an existing plunger lift installation by exploring the effects of operational variables on the well’s deliverability. Thoroughly understand plunger lift with the single-cycle and nodal analysis plots and other tools.

Tubing Performance: Assess fluid-carrying capacity of wellbores and determine effects on deliverability with changes to wellbore configurations in both gas and oil wells.

Wellbore Modeling:

Static Pressure Profile: Complete shut-in sandface pressure from wellhead pressure and liquid level in the wellbore.

Calculate wellhead to sandface or sandface to wellhead pressure traverse for wellbores of arbitrary geometry. Perform hydrates detection along the well at given flowing conditions. Detailed pressure loss computations and fluid properties are readily accessible.

Reservoir Model:

Wellbore Schematics:

Liquid Lift:

Semi-scale graphical depiction of wellbore configuration and geometry.

Determine minium flow rate for liquid lift to avoid fall-back and load-up in gas wells.

Predict initial deliverability from gas reservoirs above the dew point.

Sample plots generated from F.A.S.T. VirtuWell™

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ADVANCED PRESSURE TRANSIENT ANALYSIS

MAIN FEATURES Quick & Easy Data Entry:

Test Design:

A comprehensive system of wizards is designed to guide the through the appropriate steps to ensure data is entered properly and that they obtain a reliable analysis.

Simulate a test to determine optimal test procedure. Determine if a horizontal well should be considered as an alternative to a vertical well.

Pressure Transient Analysis (Conventional):

Analytical Modeling:

Analyze drawdown/build-up data or injection/fall-off data for gas, oil and water wells. Use both vertical and horizontal well configurations.

Create reservoir conditions from a host of analytical models to match the pressure behaviour observed during a test or during extended production/injection periods.

Pressure Transient Analysis (Unconventional):

PAS Requirements:

Analyze pressure buildup after perforating or analyze pressure falloff following frac calibration tests.

Meets ERCB Pressure ASCII Standard (PAS) requirements for electronic test data submissions in Alberta, Canada. TRG.PAS files can be easily created, viewed and edited.

Deliverability Forecasting:

Other:

Predict the deliverability of a well based on modeling results. Generate “what-if” scenarios to determine the increase in deliverability expected from stimulation or adding compression.

Analyze results from multi-rate tests to determine the components of the total skin factor. Establish IPR and OPR based on test results.

Sample plots generated from F.A.S.T. WellTest™

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