intelligent wellhead systems invision system€¦ · intelligent wellhead systems – invision...

Intelligent Wellhead Systems – inVision System

Saudi Aramco: Site #12 – HRDH -1303 Coiled Tubing Intervention

January 2020

Abstract:

Intelligent Wellhead Systems supplied a 5-1/8” 10M inVision Critical Well Intervention System to Saudi Arabia. On January

10th, 2020 the system was mobilised to Site #12 – HRDH-1303 as a part of a High Pressure Coiled Tubing and Slickline fishing

operation to recover 3-1/8” guns, 9,775’ of 9/32” alloy electric line, PEAK cable cutter and drop bar. The inVision job scope

consisted of Coiled Tubing fishing of the near surface 300’ of electric line cable. This was successfully completed over seven

days using Halliburton Coiled Tubing Unit CTU-13. The inVision System was successfully integrated with the Coiled Tubing

Unit and identified the connector location, variations in BHA and Coiled Tubing diameters, provided an extra level of safety

identifying false bump-ups and preventing well control issues associated with staging the fish out of the well.

Leaders in Critical Well Intervention Technology

Developers of the Canadian Headquarters 7633 - 57 St, SE Calgary, AB., Canada T2C 5M2 1-866-776-6578

[email protected]

US Headquarters 511 16th St, Suite 500 Denver, Colorado, USA 80202

Contents 1 Introduction ........................................................................................................................................... 2

2 System Equipment Overview ................................................................................................................ 3

3 Operations ............................................................................................................................................. 4

3.1 Mobilization: Friday, January 10th ................................................................................................ 5

3.2 Rig-Up: Saturday, January 11th to Sunday, January 12th .............................................................. 5

3.3 Operations Summary ..................................................................................................................... 9

3.3.1 January 13th - Coiled Tubing Run #1, 2, 3, 4 .......................................................................... 9

3.3.2 January 14th - Coiled Tubing Run #5 ...................................................................................... 9

3.3.3 January 15th – Coiled Tubing Run #6, 7, 8 ............................................................................. 9

3.3.4 January 16th – Coiled Tubing # 9, 10, 11 .............................................................................. 10

3.4 Rig-Down: Thursday, January 16th .............................................................................................. 13

4 Conclusion ........................................................................................................................................... 14

5 APPENDIX A ......................................................................................................................................... 17


[email protected]


1 Introduction Intelligent Wellhead Systems (“IWS”) inVision System is a technology that was developed to improve

well intervention decision making processes. This is accomplished by enabling the operator to visualize

size and location of BHA components and tubing while being tripped through the pressurized BOP stack.

The system generates a 2D image of ferrous alloy tool string components, indicating tool diameter

profiles and lateral tool location. This is achieved by combining outputs from proprietary magnetic

sensors placed radially around a specially engineered spacer spool that is installed in the PCE stack. The

system is completely non-intrusive, introducing no additional leak paths and can be installed at any point

in the PCE Stack.

The inVision System is transported in a 6’L x 6’W x 8’H container and comes equipped with fork pockets

and a 4-Leg Lifting sling for ease of transportation and equipment positioning on site. Systems designed

for KSA come with additional cooling equipment to ensure the control system is kept with-in operating

temperature.

The system shown in Figure 1.) had been previously shipped to complete the intervention operation for

Aramco TTR in April 2019. The TTR file #TR-2018-0051 was finalised in October 2019. The system was

staged out of the Haliburton UDH Base in a collaborative effort involving IWS and Halliburton.

Figure 1. HAL UDH BASE Yard 4: IWS FS03 prior to mobilising to Site #12 - HRDH-1303


[email protected]


2 System Equipment Overview The inVision System used in this TTR consists of a 5-1/8” 10M inVision spool with a 4-1/16” 10M cross-

over. The pressure containing equipment is API 6A monogramed and all wetted surfaces are Inconel 625

lined for ultra high H2S and CO2 service. Full system specification and system inventory is outlined in


[email protected]


APPENDIX A.

Figure 2.) outlines the 5-1/8” 10M inVision spool and cross over dimensions. The system weighs 780 lbs

and is 26” in height. The spool features a robust stainless-steel guard designed to protect the magnetic

sensor array and electronic components of the system against general oilfield use and direct sunlight.

Figure 2. inVision Spool Schematic

Interaction with the system is achieved through various interfaces including a wired zone rated HMI at

the wellhead controls, as well as two zone rated wireless tablet interfaces and two general zone wireless

tablet interfaces. Figure 3.) demonstrates what the inVision operator Interface looks like as a coiled

tubing BHA is run in hole. The diameter being measured is displayed to the left of the image. A visual


[email protected]


indication of lateral location and detected OD is displayed in the center and a side profile view of the

detected diameters is displayed to the right.

Figure 3. inVision Operator Interface

Critical spares and multiple system redundancies are included with each unit and all equipment is

transported in the container. See


[email protected]


APPENDIX A) for complete system specification and system inventories.

3 Operations The following section details the inVision System mobilization, Rig-Up/Rig-Down requirements and

system performance through-out the intervention. Additionally, the systems log files have been retained

should further analysis be required. The system log files are timestamped and sampled at a rate of 1 Hz.

The information contained in the log files include diameter, lateral location and bore temperature. as

detected at the point of installation of the inVision spool. The log files enable the viewer to replay the

job in real time or at an accelerated rate and view the information in both graphical form and HMI view.

The inVision System detected the coiled tubing BHA and coiled tubing string within OEM specification.

The system provided audible and visual alerts when detecting the BHA and when it cleared the inVision

spool at the end of the run. The pneumatic visual indicator system performed within specification and

provided an additional safety alert as to the presence of coiled tubing in hole, this indicator was placed

on the crown valve.

3.1 Mobilization: Friday, January 10th

The inVision System was mobilized with a Halliburton coiled tubing unit CTU-13 from Haliburton UDH

Base Yard 4 to Site #12 approximately 2 hours 20 minutes. The system was transported on a flat deck

truck and was loaded and unloaded at both ends using a fork lift.

3.2 Rig-Up: Saturday, January 11th to Sunday, January 12th

The inVision Container was positioned in front of the coiled tubing unit. 110VAC power was supplied by

the coiled tubing generator and air was sourced from the coiled tubing unit’s onboard compressor.

A zone rated HMI was located along the walk path from the coiled tubing unit to the wellhead and

behind the slick line truck, clearly visible to personnel approaching the wellhead. A tablet interface was

placed in the coiled tubing unit as shown in Figure 4.)


[email protected]


Figure 4. inVision Interface installed inside Coiled Tubing Unit

Error! Reference source not found..) Shows the inVision spool as it was installed forming part of the

riser assembly above the two 4-1/16” gate valves and the coiled tubing QUAD BOP. See Figure 6.) for

installation photograph and Figure 7.) for installation diagram. It is important to note that the inVision

spool can be installed at any point throughout the PCE stack as considered most useful for a given

intervention.


[email protected]


Figure 5. inVision Spool Installation

inVision Spool


[email protected]


Figure 6. inVision Spool installed in PCE stack

inVision Spool


[email protected]


Figure 7. inVision Spool Installation Diagram

Coiled Tubing Injector

Riser

inVision Spool

BOP Assembly

Dual Gate Valve Assembly

Wellhead


[email protected]


3.3 Operations Summary

The following section contains a summary of the fishing operations highlighting critical points of interest

as the coiled tubing BHA was run in and out of hole at surface. The fishing operation was completed

using a combination of coiled tubing and slickline. Slickline was utilized to locate fish top and coiled

tubing was used to extract the wireline fish in sections using the expandable wire grab fishing tool.

3.3.1 January 13th - Coiled Tubing Run #1, 2, 3, 4

02:15 AM - Coiled tubing completed its first run. Fish top was located at 404 ft. and 21 ft. of wireline was retrieved from the well. The retrieved wireline was deemed to be in good condition with minimal signs of corrosion or mechanical damage. 11:05 AM – Slick line operations were installed located fish top at 426 ft. 12:20 PM – Coiled tubing was installed and ran in hole to 505 ft. retrieving 9 ft. of wireline. 15:00 PM – Slick line operations commenced and located fish top at 429 ft. 16:15 PM – Coiled tubing operations commenced to run in hole locating fish top at 435 ft. and began latching on to fish. Coiled tubing operations were unsuccessful in recovering any wireline on this run. 18:00 PM – Coiled tubing operations commenced to run in hole. Issues were encountered whilst moving the BHA through the wellhead. It was determined that the fishing tool had made contact with the Master Valve which resulted in some permanent bending of the actuator arms of the fishing tool. The backup BHA was run and failed due to a stuck actuating arm. Coiled tubing operations were put on standby until new BHA’s could be mobilized to site from Weatherford Dammam base.

3.3.2 January 14th - Coiled Tubing Run #5

11:45 AM – Slickline operations were installed on the well and run in hole to compress the fish

top down hole as far as possible. The intent of this was to improve the amount of wireline that

could be retrieved by coiled tubing while waiting for replacement BHA’s to arrive.

16:30 PM – Replacement coiled tubing BHA arrived and on site testing of the new components

commenced. One of the two replacement BHA’s failed testing.

18:30 PM – Coiled tubing commenced fishing operations again, retrieving 45 ft. of wireline.

3.3.3 January 15th – Coiled Tubing Run #6, 7, 8

07:45 AM – Slickline was installed on the well and began to run in hole to compress the

remaining wireline. Slickline reached a maximum depth of 361 ft.

11:50 AM – Coiled tubing was installed and run in hole to a depth of 375 ft. retrieving 52 ft. of

wireline.

14:45 PM – Slickline was installed on the well to compress the wireline fish and reached a

maximum depth of 384 ft.

17:05 PM – Coiled tubing was installed on the well and reached a depth of 396 ft. retrieving 52

ft. of wireline.


[email protected]


21:15 PM: Slickline was installed on the well and ran in hole compressing wireline fish to a


22:54 PM: Coiled tubing was installed on the well and successfully retrieved 56 ft. of wireline.

3.3.4 January 16th – Coiled Tubing # 9, 10, 11

01:45 AM – Slickline was installed on the well and ran in hole compressing wireline fish to a


02:50 AM – Coiled tubing was installed on the well and successfully retrieved 42 ft. of wireline.

04:15 AM – Slickline was installed on well and compressed wireline fish to a maximum depth of

360 ft.

06:35 AM – Coiled tubing was installed on the well and failed to retrieve any wireline fish.

08:15 AM – Slickline was installed on the well and compressed the wireline fish to a depth of 361

ft.

11:30 AM – Coiled tubing was installed on the well and retrieved 41 ft. of wireline.

12:30 PM – Decision made to release services.

14:30 PM – Coiled tubing commenced rig out operations.

20:00 PM – IWS inVision System secured for demobilization to Halliburton Yard 4 UDH staging

yard.

One of the key objectives of inVision was to identify the CT connector as it entered the riser section.

This allowed the CT operator to stop the coil in exactly the correct location in order to cut the retrieved

cable.

The system performed within specification through out the job and detected variations in diameter

sufficient to clearly identify BHA components. Audible and visual alerts were issued by the system when

the BHA was detected while pulling out of the hole and again when the BHA cleared the inVision spool at

surface. Video play back files are included with the supporting material for this document.

The inVision System records all data in system log files. These log files are stored on the primary control

box and on each HMI connected to the system. The log files are stored in a secure proprietary format

and can be viewed using the inVision Log File viewer. A brief analysis was performed on these log files to

identify the BHA as it entered and exited the inVision spool.


[email protected]


Figure 8.) depicts the BHA as it was run in hole using the inVision Log File viewer. The inVision log files

contain detailed records of the inVision Systems measurements and can be played back post job for

analysis.

Figure 8. 01-12-2020 HRDH 1303 First run Coiled Tubing – Run in hole to 404 ft.


[email protected]


Figure 9.) References the Halliburton fishing BHA utilized on this intervention. The BHA included an

Expandable Wire Grab, Fixed Centralizer, MHA and CT External Connector to 2” coiled tubing. It is

important to note that the listed OD for each tool is the maximum OD. As can be seen in the video files

supporting this document the measured OD fluctuates in accordance with the BHA profile.

Figure 9. Halliburton BHA Schematic


[email protected]


Figure 10.) depicts the BHA as it was pulled out of hole using the inVision Log File viewer. The system log

files contain lateral location information, detected diameters and well bore temperatures. Total job

duration and other important tool-string information can be obtained from the log files for future

reference as required.

Figure 10. 01-12-2020 HRDH 1303 First run Coiled Tubing – Retrieved 21 ft. CRA Wireline

3.4 Rig-Down: Thursday, January 16th

The inVision System rig-down was performed off critical path time and took a total of 45 minutes to

prepare for transport. The inVision spool was lowered to ground level as part of the coiled tubing riser

and injector assembly. The inVision spool was disconnected at ground level and stored in the transport

container using the site forklift.


[email protected]


4 Conclusion Throughout the job the inVision System added value by consistently identifying coiled tubing diameters

as well as in hole / out of hole status and communicating this information at critical points on site through

out the operation. This information was displayed in the coiled tubing cab, primary access routes to the

wellhead and via the visual wellhead indicator attached to the crown valve on the wellhead. The interface

can also be displayed on wireless tablets which can be placed anywhere on site within range of the systems

WiFi network. The user interface was found to be intuitive and was easily interpreted by the coiled tubing

crew.

The coiled tubing crew was intrigued to witness the behavior of the coiled tubing inside the pressurized

zone of the PCE stack. The inVision System enabled the coiled tubing operators to correlate the impact of

various actions on the coiled tubing injector and other surface equipment on the coiled tubing, inside the

PCE stack. For example, while RIH the coiled tubing skipped on the reel, the resulting jolt could be seen

affecting the coiled tubing inside the PCE stack using the systems lateral location features.

It was noted that coiled tubing fatigue and wear could be reduced by using the system to adjust crane

boom angles and guy-line tensions to centralize the coiled tubing within the well bore and prevent rubbing

on the internals of the wellhead and other surface equipment.

Further advantages noted by the coiled tubing crew were often a result of past experiences where the

benefits of the system could have been realized. Some of these issues included; surface obstructions while

running in hole, false tag outs, failed depth counters, scale build up, parted tubing, slim-hole BHA’s, etc.

Many of the benefits of the system were made possible by improving operator awareness and

understanding of the behaviour of their coiled tubing inside the PCE stack, this is a data point that has

been omitted from operations until now.

On this fishing job for well HRDH-1303 the primary benefit of the inVision System was the ability to

confidently identify when the coiled tubing BHA was passing through the wellhead and had been

completely removed from the wellbore, thus, enabling the safe closing of the wellhead valves. During

fishing operations many complications can arise from misinformation, guesswork or assumptions around

the interpretation of various equipment sensors. Typical fishing procedure rely on the depth counter to

indicate when the BHA may be nearing surface; then the weight indicator is used to identify when the

coiled tubing connector has made physical contact with the stuffing box. This method becomes

problematic and can result in significant delays, equipment damage or critical well control incidence when

the coiled tubing depth counter fails, a false tag out occurs or if the coiled tubing is parted. New technology

like the inVision System now enables the coiled tubing and wireline operators to clearly identify exactly

where key BHA and toolstring components are within the PCE stack using reliable non-intrusive sensing

technology. As the inVision System becomes widespread SOP’s and new procedures are being written to

take advantage of this technology and complete jobs in ways that have not ben previously possible.

The entire Intelligent Wellhead Systems team would like to thank Halliburton Energy Services, the crews

of CTU13 and Saudi Aramco for the continuing opportunity to demonstrate value with the inVision Critical

Well Intervention System and looks forward to future collaboration.


[email protected]


InVision Application: Critical well operations

The system displays an image of the cross section of the Pressure Control Equipment (WHE) stack at the

installed location of the inVision Spool.

The following data is clearly displayed on operator and company supervisor screens:

• Tool and tubing O.D. • Lateral location of the tool, coiled tubing or wireline • Tool O.D. profile (visualization of the tool O.D. versus time as the BHA moves up

or down) Benefits:

• Reduce exposure to risk, particularly on complex operations such as fishing, milling, slim BHA, high pressure and H2S

• Increase well control and decision-making capability through increased information

• Understand exactly what component is moving through the wellhead • Immediately identify surface issues when running in or out of well • Engineered hazard mitigation • Prevent fishing operations • Prevent improper actuation of BOP and shear valve • Prevent hydrocarbon release from stripper • Remove personnel from Red Zones • Provides Verification versus Educated guessing • Enable faster Coiled Tubing / Wireline Intervention • Enable modification of specific Standard Operating Procedures (SOP) reducing

NPT • Enable efficient, accurate communication onsite between services and company

supervisor • Correlate depth counters using inVision

• Avoid HSE loss time incidents • Peace of mind for all • Detects diameter of wireline, tubulars and downhole tools through the inVision spool in real

time • Substantial increase in efficiency, safety and visibility of daily operations • Adding inVision technology to the operation safely increases the speed of live well intervention

operations. • Numerous well control risks are removed. • Reduced operator stress levels when performing certain critical tasks within a live well

intervention. • The tool adds a layer of protection in your risk matrix. • Data reports provided by the system gives clear, accurate visibility into daily operations at the

wellhead. •


[email protected]


Coiled Tubing Operation Challenges that are addressed or avoided by inVision:

• Depth Counter Inaccuracy

• Perform Bump-Up

• Exposure to Human Error

• Pull through Stripper/Injector with slim BHA

• Personnel in Red Zone


[email protected]


5 APPENDIX A This section contains system specification and system inventories.


[email protected]


intelligent wellhead systems invision system€¦ · intelligent wellhead systems – invision...

Documents