SM Energy South Texas Operations Team

Eagle Ford Shale

Wellhead Pressure Rating Field Survey

Summer 2016 Internship Project

SM Energy 20228 South US HWY 83

Catarina, Texas, 78836

Prepared by Erik Mason

emason@sm-energy.com Production Engineer Summer Intern

22 August 2016

i

Overview

The main purpose of this report is to explain the reasoning and discoveries behind the Wellhead Pressure Rating Field Survey Project. With this report it will be easy to train others to understand and use the findings from this project, as well as presenting experiences and accomplishments achieved throughout the duration of the internship.

How a field wide survey of all wells in SM Energy’s Eagle Ford Shale asset was performed in order for workover crews and future frac operations to have a reference of what wellhead components are located in the field will be the main focus of this report. To do this efficiently, flange sizes and pressure ratings were correctly identified and recorded. With this process completed, the data was entered into WellView and later connected through a live link to Spotfire to easily access and visually understand the information which was collected throughout the summer.

The major result of this report is an up to date and accurate inventory of all wells in SM’s Eagle Ford asset. In addition, now a Spotfire program has the ability to incorporate all data from the WellView database. This creates the ability for the operations team to easily locate accurate wellhead equipment information. Along with the operations team using this data, the offset frac process can also use this data to locate wells which will not meet the 10K pressure rating requirements. By having the Spotfire map, the STX Operations team can easily find all wells which will need to be shut in or modified before a frac operation begins.

ii

Table of Contents

Overview ................................................................................................................................i

List of figures ........................................................................................................................ iv

List of tables ..........................................................................................................................v

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

1.1 Scope of Project ............................................................................................................ 1

1.2 Objective ...................................................................................................................... 1

1.3 Deliverable ................................................................................................................... 1

2 Necessity of Project .............................................................................................................2

3 Project Analysis Process.......................................................................................................3

4 Initial Challenges Encountered .............................................................................................4

4.1 Understanding Wellheads .............................................................................................. 4

4.2 No Knowledge of Field.................................................................................................. 4

4.3 Painted/Rusted Flanges .................................................................................................. 5

4.4 Unique Wellhead Configurations.................................................................................... 7

5 Data Collection....................................................................................................................8

5.1 Outdated Inventory........................................................................................................ 8

5.2 Tools of the Trade ......................................................................................................... 9

5.3 Field Data Entry Sheet ................................................................................................... 9

6 WellView .......................................................................................................................... 10

6.1 WellView Prior to Project ............................................................................................ 10

6.2 New WellView Report Template .................................................................................. 10

6.3 Drop Down Menus ...................................................................................................... 11

6.4 Report Filled Out ........................................................................................................ 12

6.5 Future Data Entry ........................................................................................................ 13

7 Instructions for Entering Data into WellView ...................................................................... 14

7.1 Former Entry............................................................................................................... 14

7.2 Adding Component ..................................................................................................... 14

7.2.1 Adding Wellhead Section ...................................................................................... 15

7.2.2 Adding Manufacturer ............................................................................................ 15

7.2.3 Adding Component Name ..................................................................................... 15

7.2.4 Adding Maximum Pressure Rating ......................................................................... 16

7.2.5 Adding Flange Size ............................................................................................... 16

7.2.6 Final Product ........................................................................................................ 17

7.3 Future Updates ............................................................................................................ 18

7.3.1 Adding Installation and Removal Dates .................................................................. 18

8 Spotfire Integration ............................................................................................................ 19

8.1 Objective .................................................................................................................... 19

8.1.1 Mapping Process................................................................................................... 19

8.2 Frac Offset Project ...................................................................................................... 20

8.2.1 Fracture Radius ..................................................................................................... 20

iii

8.3 Spotfire Conclusion ..................................................................................................... 21

9 Instructions on how use Spotfire Program............................................................................ 21

9.1 Need of Spotfire Program ............................................................................................ 21

9.2 Systematic Instructions ................................................................................................ 21

9.2.1 Select Well Being Fracked..................................................................................... 21

9.2.2 Setting Radius....................................................................................................... 22

9.2.3 Running Filter....................................................................................................... 22

9.2.4 5,000 psi Well Components ................................................................................... 23

9.2.5 Final Visual .......................................................................................................... 23

9.3 Result of Program ....................................................................................................... 24

10 Results of Entire Project ................................................................................................... 24

10.1.1 Knowledge of All Wellhead Components ............................................................. 24

10.1.2 WellView Now Updated ...................................................................................... 24

10.1.3 Spotfire Program ................................................................................................. 24

10.2 Extreme Hands On Project ......................................................................................... 25

10.3 Field Exposures ........................................................................................................... 1

iv

List of figures

Figure 1: Project Analysis Process. ..........................................................................................3

Figure 2: Wellhead and Tree Schematic [1] ..............................................................................4

Figure 3: Rusted Flange ..........................................................................................................5

Figure 4: Prior to Using Paint Stripper .....................................................................................6

Figure 5: Post Paint Stripper ....................................................................................................6

Figure 6: Unique 7 1/16” Wellhead ..........................................................................................7

Figure 7 Schematic of Galvan Ranch B 115H ...........................................................................8

Figure 8: Field Use Data Entry Sheet .......................................................................................9

Figure 9: WellView Prior to Project ....................................................................................... 10

Figure 10: Template Location................................................................................................ 10

Figure 11: Wellhead Section Drop Down ............................................................................... 11

Figure 12: Manufacturer Drop Down ..................................................................................... 11

Figure 13: Component Drop Down ........................................................................................ 11

Figure 14: Max Pressure Drop Down ..................................................................................... 12

Figure 15: Flange Size Drop Down ........................................................................................ 12

Figure 16: WellView with Data Entered ................................................................................. 12

Figure 17: Galvan Ranch A541H Before ................................................................................ 14

Figure 18: Selecting B-Section .............................................................................................. 15

Figure 19: Selecting Manufacturer ......................................................................................... 15

Figure 20: Selecting Component ............................................................................................ 15

Figure 21: Selecting Maximum Working Pressure .................................................................. 16

Figure 22: Selecting Flange Size ............................................................................................ 16

Figure 23: Galvan Ranch A541H in WellView Following Data Entry ...................................... 17

Figure 24: Install and Removal Date ...................................................................................... 18

Figure 25: Menu to Choose Date of Install or Removal ........................................................... 18

Figure 26: Spotfire 5k Mapping Tool ..................................................................................... 19

Figure 27: Spotfire Frac Offset .............................................................................................. 20

Figure 28: Choosing Frac Well .............................................................................................. 21

Figure 29: Radius Slide ......................................................................................................... 22

Figure 30: Recenter Button.................................................................................................... 22

Figure 31: Radius Seen on Spotfire Map ................................................................................ 22

Figure 32: 5K Well Components............................................................................................ 23

Figure 33: Frac Radius Outcome............................................................................................ 23

Figure 34: Time Breakdown of Data Collection vs. Data Entry ................................................ 25

Figure 35: Time Break Down of Entire Summer ..................................................................... 25

Figure 36: Visit to Drill Site ....................................................................................................1

v

List of tables

Table 1: Field Data Entry Sheet of Tubing Head from Galvan Ranch A541H ........................... 14

1

1 Introduction

1.1 Scope of Project

The goal of this Wellhead Pressure Rating Field Survey Project over the duration of 10 weeks was to conduct a field wide survey of all wellheads within SM Energy’s Eagle Ford asset. This survey was meant to correctly identify all wellhead flange sizes and their respective maximum pressure ratings. Following this survey, all the data needed to be entered into an easy to access database, WellView.

1.2 Objective

The objective was to have all wellhead flanges identified and correctly entered into a WellView template. This will allow accessibility of workover crews and lease operators to use pertinent information for future reference. In addition, all data collected will be utilized for future offset-frac shut-ins.

1.3 Deliverable

The result of this project is an up to date and accurate inventory of existing wellheads. With this comes an updated WellView database. Along with WellView, there is now a Spotfire program, which allows for easier management of data and visualization of the data.

2

2 Necessity of Project

The benefits of this project are enormous. The amount of man-hours saved will be immense now that operators will no longer need to be sent out on location to visually inspect a wellhead before each frac operation. Along with saving time in terms of man-hours, it is also recognized that no well within the field was overlooked and all data was correctly identified. The need for this data is essential due to the possibility of wellbore communications during a frac operation. If a frac communication occurs, there is the risk of a blow out if the offset well does not meet the pressure ratings above that of the frac. The requirement of this data was seen firsthand in March of 2016 when a wellhead pressure rating was overlooked. The components were only rated to 5K PSI while frac operations were at approximately 9K PSI. Upon arrival at the wellhead, pressures were reading near 4,500 PSI, which was quickly approaching the failure rate of the wellhead component. This project mitigates that risk from happening again.

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3 Project Analysis Process

The sheer amount of time that this project required meant that time management was key. This meant creating a layout shown in Figure 1 of how time would be spent from the beginning up until the very end when conclusions and results were discovered. In the beginning, I needed to understand all data that was needed and missing for the wellheads throughout the field. This information was then cross-referenced with previous data. Following data collection, a template was created in WellView that would be easy to access for everyone to continually update as the field grows and matures. After entering all of the data in the WellView database, it was then time to link this data into a Spotfire project for future field operations. Following all of this, conclusions and recommendations could be delivered.

Figure 1: Project Analysis Process.

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4 Initial Challenges Encountered

4.1 Understanding Wellheads

From the start, a large learning curve came with this project. First was becoming familiar with all of the different sections of a wellhead, from the A section to all the way up to the production tree as seen in Figure 2 below. After being acquainted with all the different sections and components, it was essential to research the various types of artificial lift methods located throughout the field to properly collect the necessary data.

Figure 2: Wellhead and Tree Schematic [1]

4.2 No Knowledge of Field

Along with these challenges was the element that an understanding of field locations and number of wells would be necessary. Without this knowledge, there was a risk of missing wells or entering areas of the Galvan or Briscoe Ranches that were off-limits to oilfield traffic. With the help of everyone in the field, along with the search and discovery of hand drawn maps and updated google maps found throughout the numerous shared files, a grasp of the field layout was finally achieved.

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4.3 Painted/Rusted Flanges

The most challenging issue faced during the data collection period was paint and/or rust concealing the flange size and max pressure rating on each valve of the wellhead as shown in Figure 3.

Figure 3: Rusted Flange

Originally, it was thought that a simple wire brush similar to that of which cleans a barbeque would be suitable for the job. Upon further discovery in which over an hour was spent cleaning half of a wellhead, it was apparent that a different process of cleaning the valves was necessary. This is when the maintenance team recommended using high-grade gasket cleaner to remove any residue from the area of the flange where the desired data was located. This recommendation worked tremendously. A simple spray of the cleaner along with a small amount of scuffling with the wire brush and the paint or rust simply wiped right away as shown on page 6 of the former and post state of the flange in Figure 4 and Figure 5. After this problem was mitigated, data collection was able to begin.

6

Figure 4: Prior to Using Paint Stripper

Figure 5: Post Paint Stripper

7

4.4 Unique Wellhead Configurations

Even with an understanding of the different wellhead configurations throughout the field, the occasional standout was found. Multiple calls were made to colleagues in order to understand certain wellhead set-ups. In some cases, wells were discovered which no one throughout the STX Operations field office even knew were configured in such a way. The one which stood out the most is shown below in Figure 6. This wellhead was found midway through the summer and took a large amount of collaboration to understand why it was configured in such a way. This 7 1/16” tubing head was necessary due to the well not currently producing, and having high H2S levels.

Figure 6: Unique 7 1/16” Wellhead

8

5 Data Collection

The process of collecting the required data was the most time consuming portion of the entire project. Each well flange required hand inspection as they all differed in size and pressure rating. Along with this, SM Energy produces from approximately 430 wells in the Eagle Ford Shale. To put the amount of time into perspective, the average free flowing production tree has at least 12 flanges which needed to be inspected. So in the course of three and a half weeks, approximately 4,000 flanges were visually inspected to obtain the size and max pressure rating.

5.1 Outdated Inventory

From the start of the data collection, research was done throughout Network Shared Drives to seek out any previous inventory which was completed that would benefit this project. Through that exploration, a file was found that contained inventory and schematics of all Cameron wellheads throughout the field. At first, this seemed to be a huge breakthrough for time purposes of being able to double check each well and not have to alter anything on these inventoried wells. Upon arriving at the Galvan Ranch B 115H shown below in Figure 7, it was apparent that these schematics would be of no help due not only to them being from 2013, but also because most of the wells had been altered in three years’ time. This just furthered the awareness of how daunting of a task it was going to be to visit all 430 wells in such a short time period.

Figure 7 Schematic of Galvan Ranch B 115H

9

5.2 Tools of the Trade

The tools necessary to complete this project are listed below:

PPE o Safety Glasses o Face Mask o Gloves o FRC’s o Hard Hat o H2S Monitor

Hand Wire Brush Paint Stripper

o Overcame issue of Paint/Rust

Rags

Data Entry Sheet

5.3 Field Data Entry Sheet

In the field there needed to be a convenient way of tracking data for each well before being entered into the WellView database. A printable data entry sheet shown in Figure 8 was created using Excel Spreadsheet. This sheet was used at each wellhead to record the flange sizes and their max pressures by hand before returning to the office to input the data.

Figure 8: Field Use Data Entry Sheet

10

6 WellView

After collecting all the wellhead data for 430 wells, it needed to be entered into a companywide accessible database. This is where WellView was put to use. Historically, data entry for a wellhead stopped after drilling was completed as seen in Figure 9.

6.1 WellView Prior to Project

Prior to this project, wellhead component data was not available in WellView. If information was needed from a wellhead for a workover or a frac shut-in, the lease operator was sent out to location to gather the information. Even after the lease operator gathered the data, it was never tracked. This meant extensive amounts of man hours spent traveling to and from wells due to the information not being accessible from a database.

Figure 9: WellView Prior to Project

6.2 New WellView Report Template

Knowing that there needed to be an area for this data to be input, time was spent with Eileen Kosakowski from the Houston regional office to create a user-friendly report template. The report is located in the Houston Production Input drop down option seen below in Figure 10. The report is named Wellhead Pressure Integrity. On page 13, there are systematic instructions that will walk through the exact process of entering data into this report.

Figure 10: Template Location

11

6.3 Drop Down Menus

The new template needed to be user friendly due to the massive amount of data that needed to be input. This meant creating drop down menus which were prefilled with all the different sections of the wellhead, manufacturer, model (component), and max pressure along with top and bottom flange size. By having drop down menus, the report remains standardized throughout the entire field, which became crucial at the end of this project when the WellView data was integrated into Spotfire. Along with the drop down menus, the report allows for the user to enter the date of when something is added or removed from the wellhead so that inventory remains correct moving forward.

Figure 11: Wellhead Section Drop Down

Figure 12: Manufacturer Drop Down

Figure 13: Component Drop Down

12

Figure 14: Max Pressure Drop Down

Figure 15: Flange Size Drop Down

6.4 Report Filled Out

After entering all the data for a given well into WellView, it is available for everyone to use. This means that workover crews can access the flange sizes they need to order for new tree set-ups. The Operations Team knows the max pressure rating of the entire wellhead in order to determine if the well can just be shut-in for offset-frac, or if a plug needs to be placed at the 2-way valve in the hanger. Shown below is a completed Wellhead Pressure Integrity report for the Galvan Ranch A541H in WellView.

Figure 16: WellView with Data Entered

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6.5 Future Data Entry

With the standardized set up of the new report, entry of future data will be quick and simple. Being as every well currently located in the field is up to date in WellView, changes can quickly be made as trees are reconfigured or switched for artificial lift. It is critical that the reports are kept updated as changes are made. In order to ensure this happens, I personally trained the Catarina Field Office Engineering Techs along with the Completions team in Houston. In addition, systematic instruction can be found in the next section of this report along with a separate report of only the instructions for future training of individuals which can be found in the Catarina Shared Drive, R:\Shared\Workover\Wellview Input Directions.

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7 Instructions for Entering Data into WellView

This section will go through the systematic process of entering wellhead component data into the Wellhead Pressure Integrity report in WellView following visual inspection of the wellhead. The Galvan Ranch A541H will be used for this demonstration.

7.1 Former Entry

As shown below, the wellhead components section is empty even though the well status shows it as a producing well.

Figure 17: Galvan Ranch A541H Before

7.2 Adding Component

In WellView, the components will automatically order themselves by section starting with the B-Section and work down the report to the production tree which is opposite from an actual well which starts with the B-Section and goes up to the Production Tree. There is also an A-Section on every well however most are buried, so the focus was put on the accessible sections which were the B-Section and Production Tree. For this demonstration, we will enter the tubing head with the data which was found on site. Below is the data entered into the field data sheet on Excel.

Table 1: Field Data Entry Sheet of Tubing Head from Galvan Ranch A541H

B-Section Manufacturer Flange Size(IN) Max Pressure Rating(PSI) Additional Comments

Tubing Head Seaboard 5 1

8 10,000 NONE

Empty Wellhead Components

Well Status

15

7.2.1 Adding Wellhead Section Begin by selecting the drop menu above Section and select B.

Figure 18: Selecting B-Section

7.2.2 Adding Manufacturer Next, select the Manufacturer of the wellhead component, the tubing head. In this case, Seaboard.

Figure 19: Selecting Manufacturer

7.2.3 Adding Component Name Select the Component name labeled “Model” in WellView. In this situation, the Tubing Head is selected.

Figure 20: Selecting Component

16

7.2.4 Adding Maximum Pressure Rating Use the drop down menu to select the maximum working pressure of the component. In all cases where the maximum pressure rating goes from a higher rating to a lower rating, enter the lower rating as that is the pressure at which the flange will fail. Here the tubing head has a maximum pressure rating of 10,000.0 psi.

Figure 21: Selecting Maximum Working Pressure

7.2.5 Adding Flange Size Finally, enter the flange size. In the case of an adapter, the flange size will change over to a smaller size to fit a Master Valve. The template has a second flange size drop down to add the other size.

For this tubing head, the flange size is 5 1

8 inches.

”

Figure 22: Selecting Flange Size

17

7.2.6 Final Product Shown below is what the WellView report will look like for the entire well after all component data is entered for the Galvan Ranch A541H.

Figure 23: Galvan Ranch A541H in WellView Following Data Entry

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7.3 Future Updates

Now that all existing wells are updated in WellView, as changes are made the only thing necessary is to select a removal date of the component and then add the new component data along with the installation date. In addition, as new wells are added to WellView, it is crucial to add the dates of installation to know if WellView is continually being updated so that the Spotfire Program discussed in the following section has accurate data.

7.3.1 Adding Installation and Removal Dates The installation and removal dates are also drop down menus to allow for exact date and time of when the data was entered into the system.

Figure 24: Install and Removal Date

Figure 25: Menu to Choose Date of Install or Removal

Choose if removing or

installing component.

Select Date

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8 Spotfire Integration

8.1 Objective

Initially, the goal was to merge all of the wellhead data along with their locations onto a map of SM’s leases. The reasoning behind this was so that all wellhead pressure ratings could be easily visible by location throughout the field.

8.1.1 Mapping Process In order to accomplish the task, a live link was generated with WellView, meaning that as the data is entered into WellView, it automatically updates within Spotfire. This is why it is so crucial to keep WellView updated. Next, the latitude and longitude of each well along with its wellhead data was plotted on a map. Upon completion of the map layout, a filter was set to show the wells by color based on maximum pressure ratings of the wellhead. The red spheres on the map depict wells consisting of pressure ratings below 10k while 10k and above appear as green spheres. This filter scheme can be seen in the figure shown below.

Figure 26: Spotfire 5k Mapping Tool

5k wellhead

10k wellhead

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8.2 Frac Offset Project

Following the mapping portion of this integration came the notion to make the data applicable to the offset frac shut-ins. This is an overview of the process to accomplish this project. Section 9 contains systematic directions of how to use the Spotfire Project when planning offset well shut-ins.

8.2.1 Fracture Radius After further collaboration with Blake, it was determined a script could be written to generate a radius around the planned fracking operation. By creating this script, a circle of a predetermined radius is casted over the wells surrounding the selected well. The wells within the radius are filtered based on maximum pressure rating. All wells consisting of wellhead components below the required 10k psi rating are sorted into a data table above the map. The data table shows well by well those which do not meet the required pressure rating, showing the component and its location on the wellhead. Having this information at the click of a button allows the operations team to determine, without having to send personnel out to location, if a trinity plug needs to be put in the wellbore, or if the component(s) can be isolated by closing other valves on the wellhead.

Figure 27: Spotfire Frac Offset

Wells with

components

less than 10k

Component

and wellhead

section

Frac

Radius

Slider to

determine

radius

21

8.3 Spotfire Conclusion

Now that a Spotfire program exists, the amount of time spent planning offset well fracs is much lower. The wells that are within the possible fracture communication zone can be quickly found. Along with that, shut-in time is also less due to knowing which wells only need valves shut versus those which need a plug inserted. All of this can now be done without extra man-hours being spent going to each well to make that decision.

9 Instructions on how use Spotfire Program

This section will go through the systematic process of using the Spotfire Program prior to a frac operation. Being as there is a live link between WellView and this Spotfire Project, the well will automatically populate itself on the map prior to when this program is needed.

9.1 Need of Spotfire Program

In order to know which wells are within a certain radius of the bottom hole location of the well getting fracked a radius script is used. The program then filters through all of the wells located within the predetermined radius and populates a specific data table. This table shows all wells which have components which are below 10k maximum pressure rating, along with the section. By having the data on these wells, operations can then make a decision based on the location of the component(s) on whether to close other valves that meet the required pressure rating to isolate the one(s) that do not, or set a plug in the wellhead to avoid a valve failure if wellbore communication was to occur during the frac.

9.2 Systematic Instructions

For this demonstration the Briscoe C 61H will fill the role of being the frac well.

9.2.1 Select Well Being Fracked The first step is to select the well that is on the schedule for frac operations.

Figure 28: Choosing Frac Well

Select Frac Well

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9.2.2 Setting Radius Next, go to the upper right hand table, labeled text area. Choose the radius that was predetermined to be the most likely farthest distance wellbore communication may occur.

Figure 29: Radius Slide

9.2.3 Running Filter Finally, hit the button that says “Recenter”. A circle will appear around the well selected. This is the radius used to determine wells which might get hit by offset frac.

Figure 30: Recenter Button

Figure 31: Radius Seen on Spotfire Map

Use Slider to

Choose Radius

Click to

Create

Radius on

Map

23

9.2.4 5,000 psi Well Components Along the top of the screen, all the wells which do not meet the required pressure rating will populate in a data table. They will be grouped according to Well Name and then show the component and wellhead section location.

Figure 32: 5K Well Components

9.2.5 Final Visual Shown in the figure below is what a typical Spotfire screen will look like after running the radius script to locate all under rated wellhead components.

Figure 33: Frac Radius Outcome

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9.3 Result of Program

The biggest impact from this project is the data is all in one location and operators do not need to be sent to inspect each wellhead component. The operations team can use the data pulled from the radius script and filter during the planning stage of an offset frac operation to determine all the wells which need to be shut in and then those which need further attention due to a maximum pressure requirement not being met.

10 Results of Entire Project

This project was extremely daunting from the very beginning. Time management was crucial; each day consisted of morning meetings, a certain amount of wells visited in order to finish in time to correctly enter the data, along with gaining as much field exposure as possible.

10.1.1 Knowledge of All Wellhead Components Communication was critical. Workover crews needed specific data, which meant going to well sites with the Workover Superintendent, James “Skinny” Craig, who walked through multiple wellhead configurations in order to clarify all necessary data which needed to be collected. This included showing what all flange sizes needed to be recorded, the location of the max pressure stamp and the name of each component found on a wellhead in order to keep a standardized identification system throughout the field. After understanding what needed to be recorded, all flanges from the existing wells in the entire field (approximately 430) were individually inspected and the data was hand collected. To put this into perspective, over 4,000 flanges were individually inspected by hand before being entered into WellView to ensure accuracy of all data.

10.1.2 WellView Now Updated Upon completion of the field survey, a template was created in WellView. This template became the Wellhead Pressure Integrity report, which is designed with drop down menus to ensure a standard throughout the system. The design of the report revolved around being user friendly in order to ensure that it would continue to be used after my departure. With this new report created, all the handed collected data was then input to WellView to ensure that the entire system is now updated with what is actually in the field.

10.1.3 Spotfire Program Along with WellView, now a Spotfire Program has a live link to WellView. The purpose of this program is to have all wellhead data available for frac operations to eliminate the need to send operators out to check wells during the shut in process.

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10.2 Extreme Hands On Project

Being as this was a field-based internship, it was known that most of the summer would be spent in the field. It was not until I performed a time analysis that it truly stood out how much time was actually spent out in the field. In the three and a half weeks spent collecting wellhead data, over 300 hours were spent in the field. More than 3,000 miles were driven in order to reach all 430 locations, which is over 800 miles more than it took to drive from Montana to Catarina. The figures below show the time breakdown of every hour spent working on this project, from collecting data, to WellView data entry, and finally creating the Spotfire Program.

Figure 34: Time Breakdown of Data Collection vs. Data Entry

Figure 35: Time Break Down of Entire Summer

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Bibliography

[1] Tiger Valve Company, "Typical surface wellhead systems components," [Online]. Available: http://www.tigervalve.com/typical-surface-wellhead-systems-components.html.

[2] G. Meisa, "The difference between a wellhead & Christmas tree," 2009. [Online]. Available: https://www.croftsystems.net/oil-gas-blog/the-difference-between-a-wellhead-christmas-tree. [Accessed 30 7 2016].