SPE-ICoTA Round Table 2010 Abstracts
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1. Bringing Wireline and Coiled Tubing to New Frontiers on a Light Well Intervention Unit.
Cecile Drange (Aker Solutions, Aker Oilfield Services AS)
2. Unique Straddle design for placement inside damaged Down Hole Safety Valve nipple seal area.
Tor Henning Liland (StatoilHydro), Are Lund (StatoilHydro), Therese Johanson (StatoilHydro), Espen Hiorth (BTU), Bjørn Bill (PI Intervention)
3. Milling Out Plugs in Bakken Horizontal Wells with the Aid of a Coiled Tubing Tractor.
Ernie Krueger/ Western Well Tool, Eric O’Neal/ Western Well Tool, N. Bruce Moore/Western Well Tool
4. Riserless Well Intervention Units
Siri Nordbø Jøssang, Island Offshore
5. New Technology Provides Unique Logging and Mechanical Manipulation Options in High Angle Wells by Means of Composite Spooled Rod. A Case History Covering Offshore Intervention.
David S Ottesen, Ziebel
6. TAM International
7. New Real-time Data Communication System Enhances Coiled Tubing Operations
BJ Services and Talisman Energy
8. Onshore testing of a tubing repair solution using an expandable metal patch
READ Well Services
9. The Stroker-ZIP – Zonal Isolation Plug - ensuring optimal positioning of Wireline set permanent plug
Aker Solutions
10. Modified Kick-Over Tool - enabling possibilities for replacing Gas Lift Valves in highly deviated and horizontal wells on Wireline
Aker Solutions
11. Design, Installation and Operating Experience from Nexen’s 1st Intelligent Well
Nexen
12 .Advances in 3D wellbore imaging through the development of next generation ultrasonic inspection technologies
Seawell
13. High load coil connectors for chrome coiled tubing
Hunting Welltonic
14. Locating well integrity failures precisely using ultrasound technology
Seawell
15. Onshore testing of a tubing repair solution using an expandable metal patch
READ Well Services
16.
A successful application of coiled tubing-deployed slow rotating jet cutting of tubing
Halliburton
17. Wireless casing collar locator technology aids successful depth control for hydrajet perforating with coiled tubing
Halliburton
18. KA 16 water injector well integrity recovery
Centrica Energy Upstream
19. CT-conveyed sand jetting perforation on deep tight gas well, treatment fluid selection and application perspective
BJ Services and Kelco Oilfield Group
20. Using MARS (multiple application re-injection system) technology for improving oil recovery and reducing production risk
Cameron
21. Fiber optic enabled coiled tubing optimizes well interventions in the Val D’ Agri field in Italy
Schlumberger and ENI
22. A production and workover unit based on a monohull floater
Goof Zijderveld and Leen Poldervaart of GustoMSC and SBM Offshore
23. New higher strength coiled tubing developed to extend coiled tubing operating envelopes
W. D. Van Arnam, SPE, Dale Klink, SPE, and Jack Tackitt, SPE, Quality Tubing
24. The new API standard for coiled tubing, and results from the SR 37 assessments
Presenter: Roderic K Stanley
Company: itRobotics Stafford, TX, and International Oilfield Services, Lafayette, LA, USA.
25. Coiled tubing development for subsea wells
Eamonn McGennis, Helix Well Ops
26. Application of heavy duty wireline fishing techniques to successfully retrieve well obstructions
Shell UK and Ralph Macaulay, John Vincent - Weatherford International
27. Heavy duty wireline fishing techniques utilised to successfully retrieve well obstructions through the provision of a cost effective solution allowing for the continuation of workover operations
Shell UK and Ralph Macaulay, John Vincent - Weatherford International
28. Sixteen wells abandoned without a rig – case study / Title to be confirmed
Neringa Dugnaite, Halliburton
29. Increased production with through tubing remedial sand screen deployment using inflatable straddle conveyed on e-line tractor
Richard McKee, Baker Hughes
30. Vacuum cleaning gas wells with concentric coiled tubing - Ravenspurn North NUI heavy duty wellwork project
Ann Davies, BP
31. Rigless separation of seized well flanges
Guy Bromby, ThinJack
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Abstract 01
Abstract 01
Bringing Wireline and Coiled Tubing to New Frontiers on a Light Well Intervention Unit
Presenter: Cecilie Drange, Aker Solutions, Aker Oilfield Services AS
AKOFS Proposal:
The paper will discuss the introduction of a new method of completing wells whilst reducing the amount of time spent by rigs on each well drilled.
The information presented in the paper will enable operating companies to rethink their way in which they use their drilling rigs today, and allow for more of the completion phase to be performed by lighter services such as coiled tubing and wireline.
Based on this new method of completions, up to 16 days per well can be saved on rigs per well. By utilizing this new method of completing wells, allows coiled tubing and wireline to move into a more dynamic market from a light well intervention vessel with a stiff riser solution.
This paper will explain how the use of coiled tubing and wireline in a much more effective way on subsea wells will increased the income of the operating companies , increase the use of known technology on wells where this has not been available before and explain how this set-up will allow for operations in harsh conditions from light well intervention units.
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Abstract 02
Unique Straddle design for placement inside damaged Down Hole Safety Valve nipple seal area
Tor Henning Liland (StatoilHydro), Are Lund (StatoilHydro), Therese Johanson (StatoilHydro), Espen Hiorth (BTU), Bjørn Bill (PI Intervention)
Up until today operators have been facing a challenge on how to avoid recompletion of wells where the nipple seal area inside the TRSCSSV (Tubing Retrievable Surface Controlled Subsurface Safety Valve) is damaged due to large amount of well interventions or damaged due to corrosion.
Various methods have been used for repairing a TRSCSSV with a damaged seal area. This include standard insert WRSCSSV (Wireline Retrievable Surface Controlled Subsurface Safety Valve), with normal and oversize swell packing elements. Honing of the upper and lower seal area prior to installing an insert valve has also been performed but with variable success.
To have the DHSV working properly is vital to maintain barrier control of the well. If the DHSV nipple profile is damaged the alternatives is to repair it using one of the above mentioned methods or to secure the well for later recompletion
Since all the above mentioned methods of repairing a damaged seal area for insert valve have failed, StatoilHydro initiated a development project for a straddle design using well know element technology based on BTU’s HPHT Bridge Plug design. The straddle is using solid elements, this will allow the elements to be shaped according to the damage inside the seal area. In addition each element is equipped with expanding anti-extrusion back-up rings on both sides, trapping the element so it has nowhere to go when differential pressure is applied. The straddle is using the existing nipple profile above the no-go for anchoring and is equipped with dogs to fit this profile. A
standard insert safety valve is made up to the bottom of the straddle and is then operated by existing surface control line.
This paper will compare the different methods used for repairing a damaged Down Hole Safety Valve nipple seal area, discuss the development process and qualification testing done for the new unique straddle system and setting tool. Case histories will also be presented from several prolific North Sea wells.
NOTE
This is an SPE Paper Nr 130520 that was first presented at the SPE/ICOTA in Houston last month. It has also been presented at an SPE conference in Saudi Arabia and at the One Day Seminar in Bergen and will be presented at the Stavanger ICOTA meeting.
It might be worth mentioning that we now have a development for Talisman UK for this type of equipment.
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Abstract 03
Milling Out Plugs in Bakken Horizontal Wells with the Aid of a Coiled Tubing Tractor (SPE Paper 130631)
Ernie Krueger/ Western Well Tool, Eric O’Neal/ Western Well Tool, N. Bruce Moore/Western Well Tool
The Bakken offers the largest potential for technically recoverable reserves in the US; that potential has increased because of new practices utilizing multi stage frac operations. Many Bakken wells have long cased horizontal sections up to 10,000 feet with composite plugs/frac ports set at 500-1000 ft intervals allowing greater fracture uniformity along the producing horizontal section.
After frac, current practices dictate that the well must be cleaned and the plugs milled to facilitate maximum future production. This operation has frequently been accomplished using coiled tubing alone. However, the length of the horizontal section of these newer wells frequently results in some plugs being left behind in the well due to CT’s inability to perform operations at or near TD.
An improvement to current practices would be to utilize a coiled tubing tractor to clean out and mill the remaining plugs past the reach boundaries of CT alone. This new practice was implemented successfully on two wells in the Bakken resulting in fewer plugs (zero plugs in one case) left in the well and increased future production. The case histories of these two wells along with lessons learned are described.
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Abstract 04
Riserless Well Intervention Units
Siri Nordbø Jøssang, Island Offshore
Island Offshore has since 2005 been operating riserless well intervention units in the North Sea. The first unit has successfully performed more than 50 well interventions since start April 2005. Another two units have been put into operation in 2009. Both are purpose built based on experiences gathered from the first unit.
The presentation will discuss the operating experiences from the first years and how these experiences have influenced two second generation well intervention units.
Further, the presentation will also discuss challenges for this type of service as well as future opportunities
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Abstract 05
New technology provides unique logging and mechanical manipulation options in high angle wells by means of a composite spooled rod. Case history covering offshore intervention
David S. Ottesen, Ziebel
The Z-System is a revolutionary new intervention method that facilitates high quality data acquisition that in turn is used for interpretation and analysis of the wells performance. The system is designed for highly deviate and horizontal wells and provides information beyond current technology with efficiency beyond what has been seen before.
The technology has been presented in SPE-106507 and SPE-121459-PP. This paper will describe actual deployment offshore in the Norwegian Sector in the North Sea.
The paper will discuss results and learning’s from the first offshore deployments worldwide and discuss the impact this technology has on the efficiency of data acquisition intervention and therefore well uptime.
Operational efficiency is a key factor in today’s offshore activities, often well understanding and hence optimized production over time suffers as the systems required to obtain the information is cumbersome and inefficient
The Z-System in addition to providing the highest quality information offer unique solution to the efficiency challenge and results demonstrating this will be presented
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Abstract 11
Design, Installation and Operating Experience from Nexen’s 1st Intelligent Well
G.MacKinlay (Primary Author & presenter) and C.Durham (Co-author), Nexen
The Jarvis Zechstein carbonate reservoir underlies the Ettrick field in the UK North Sea. Uncertainty over recoverable volumes meant that a Jarvis only development well would not be economic, and the pressure difference between the reservoirs meant that commingled flow was not an option. Instead, the well was completed with Intelligent Well Technology (IWT) to allow remote, open/closed flow control from either reservoir.
Apart from being Nexen’s first IWT well, the completion design incorporated several other ‘firsts’ for Nexen UK including open hole completion with swell packers in the Jarvis and TCP with Nplex/Nsqueeze fluid loss pill in the Ettrick.
The presentation will include lessons learnt about the design, installation, well testing and potential interventions planned for IWT wells. It will also include an update on the operation of the IWT sleeves since the well came on stream in December 2009, and the reservoir management information that has been gained as a result.
Abstract 12
Advances in 3D wellbore imaging through the development of next generation ultrasonic inspection technologies
Tobben Tymons, Seawell
This presentation describes a new ultrasound-based technology that is capable of producing powerful images and measurements of complex well geometries for the diagnosis of well integrity issues. By compiling multiple measurements taken at varying depths of investigation it is possible to reconstruct the downhole environment in true 3-dimensional space with the ability to examine the subject layer by layer with functionality comparable to that offered by CAD design tools.
Through the introduction and review of field trial and test well examples we will introduce the applications of this groundbreaking technology that include the imaging and measurement of wellbore obstructions in opaque fluids, the diagnosis of complex component failures such as safety valves, the determination of tubular integrity through layers of deposition and the inspection of completion components outside the tubing.
Abstract 13
High load coil connectors for chrome coiled tubing
Tony LaPlante, Hunting Welltonic
Chrome coiled tubing is becoming increasingly popular and as a result, Hunting Welltonic were approached to design and develop suitable connectors.
The connector provides an interface between the blank end of a length of chrome coiled tubing and a tool string, completion component or a BHA. To date, these chrome connectors have been deployed as part of completion assemblies. They have been designed to withstand high loads, both axial and lateral and have been fitted to tubing with high chrome content.
The Slip type connectors are suitable for tubing, up to 1-1/2”diameter, however fitting these connectors to 2”diameter tubing and above can be problematic. For this reason, the WellGripp? connector was developed. This design consists of a one piece Body and Slip. The unique feature of this coil connector is the Slip design, it spreads the radial forces produced by axial loading, ensuring the assembled component has greater strength than the tubing it is fitted to. Also the short length of the one piece body, makes it extremely easy to fit to larger coil sizes with a tight bend radius.
This, patent applied for, WellGripp? technology has been extensively tested and will have its first field run summer 2010.
Abstract 14
Locating well integrity failures precisely using ultrasound technology
Ken Feather, Seawell
Maintaining well integrity throughout the life cycle of a well is a never-ending challenge for operators. The need to secure hydrocarbons in more difficult locations, the increasing complexity of wells, and the rising number of ageing wells are all factors adding to that challenge.
With this in mind, improving the effectiveness of well integrity management is essential. Not only does this result in reduced operating costs, it can also decrease the likelihood that health, safety and environmental hazards will arise. To achieve this goal, faster, more accurate diagnosis and location of problems is a priority. Operators need to know that costly interventions will produce reliable, unambiguous data that enables remediation decisions to be made with confidence and implemented with precision.
Seawell has commercialised a system of diagnostic tools which meet that need. The system accurately locates well anomalies in the tubing and, beyond the tubing in surrounding casing strings and it exploits the properties of ultrasound.
Following a brief introduction to the technology and the various system components, several case studies will be presented from around the world, demonstrating the applications and benefits of this new diagnostic resource.
Category suggested:
Well integrity / Well intervention
Abstract 15
Onshore testing of a tubing repair solution using an expandable metal patch
Alex Crossland and Andy Gorrara, READ Well Services
The paper presents a review of the onshore qualification testing for oil and gas well applications of the Hydraulically Expanded Tubular System (HETS) Internal Patch and Wireline Running Tool by READ Well Services. The HETS Internal Patch provides a solution for tubing or other leaking downhole equipment to be repaired, or the strengthening of corroded or damaged completion equipment with minimum restriction to the wellbore.
A Joint Industry Project (JIP) was created through the Industry Technology Facilitator (ITF) with READ Well Services and 5 major oil and gas sponsors to downsize existing HETS technology to suit 4 ½” to 5 ½” tubing.
The paper describes the onshore trials and successful test well deployment on depth of a patch on wireline. The patch was subsequently tested in accordance with ISO 14310:V3 standards to 5500psi burst and 3000psi collapse. Live well deployment is anticipated in the second half of 2010 and the results of any deployment will be discussed in this paper (subject to operator permission).
The SlimHETS Internal Patch represents a new development for well design, new opportunities to extend well life and offers significant advantages over other solutions with improved access to repaired wells.
Abstract 16
A successful application of coiled tubing-deployed slow rotating jet cutting of tubing
Kritsana Kritsanaphak and Mohamed Zeghouani, Halliburton Energy Services
When it comes to plugging and abandoning wells, some well intervention work often is required to be performed, such as setting cement plugs, and cutting and pulling tubing. There are several methods for cutting the tubular in the well including abrasive jet cutting which becomes more demanding in Algeria due to the restriction of explosive use and delivery. Previously, the slow rotating tool with nozzle was typically used for scale blasting. This tool could also be equipped with a cutting head and used for cutting tubular.
This paper will discuss a successful field application of using a coiled tubing deployed slow rotating jet cutting tool on tubing. The process consists of pumping abrasive fluid through jet nozzles dressed on a cutting head equipped with the slow rotating tool. The job design was optimized to ensure an effective tubing cut. The case histories are presented with clear indications of tubing cut achieved during the jobs.
This successful application helps operators to save time, achieve reliable planning and be able to maximize the benefit of utilizing the coiled tubing unit to perform most of well preparation works and make the well ready for Hydraulic Workover to pull out the tubing.
Abstract 17
Wireless casing collar locator technology aids successful depth control for hydrajet perforating with coiled tubing
Kritsana Kritsanaphak, Salah Tirichine and Mohamed Zeghouani, Halliburton Energy Services
Recently, there has been an increasing demand for non-explosive perforating in Algerian oil and gas fields due to the regulations restricting use and transport of explosives. This often will lead to excessive non-productive time associated with waiting on shape charge explosive delivery to perforate a well. Therefore, Hydrajet perforating deployed with coiled tubing has become an alternative solution to this problem. Depth control is crucial for well perforating and the conventional coiled tubing depth control methods are sometimes not sufficiently accurate. There are several methods for depth correlation with coiled tubing and using wireless casing collar locator (WCCL) is one of the most effective methods to make accurate depth determination.
The WCCL tool is deployed on the coiled tubing and does not require an electric cable inside the coiled tubing string. It is operated by low rate circulation of an incompressible fluid through the coiled tubing and out circulating ports on the tool. When the tool is being run and passes a collar, an electric signal is generated which activates a solenoid valve to close the circulation ports for 3 seconds resulting in a pressure pulse up inside the coiled tubing. This pressure pulse is recorded at surface and displayed on a standard log format in real time. Therefore, the coiled tubing can be flagged at accurate depth for Hydrajet perforating.
This paper will discuss the successful implementation of using the WCCL for depth correlation for Hydrajet perforating with coiled tubing. The results are quite evident that the tool gives very precise depth for perforation as presented in several case histories from Algeria. The gamma-ray log run after the Hydrajet perforating job has also confirmed that the perforations were made on the right depth despite a small targeted interval of only 2 meters.
Abstract 18
KA 16 water injector well integrity recovery
Gavin Mundie, Centrica Energy Upstream
Kittiwake well KA16 was drilled and completed in 1991 as a water injection well which has injected a total of 64 MMbbl at rates of up to 1800 m3/d. Routine wellhead maintenance identified a failed UMV and tubing to ‘A’ annulus communication, an intervention commenced in April 2009, which repaired the UMV and used a combined PLT/calliper to identify the communication points.
After identifying the leak path on a pup joint just above a 4.313” AF nipple and the production packer, the safety valve was locked out and confirmed using a flapper investigation tool. A two part 5 ½” straddle was selected to isolate the communication, the lower section was run and set without issue, unfortunately after setting the upper section of straddle, the "straddle running tool" hung-up when pulling back through the previously locked open DHSV. The wire was broken close to the rope socket and a fish was left in the well, and to complicate matters, the straddle failed to test to isolate the leak path. The well remained shut-in until a plan was developed to recover the fish and isolate the 'A' annulus.
An attempt to lock open the DHSV again was made but the damage caused by the straddle running tool prevented this and a hold open sleeve was set to enable the fishing intervention. The fish had the same OD as the hold open sleeve, so it was planned to pull the hold open sleeve with the fish. The fishing operation was completed first time with no issues picking up the hold open sleeve - controlled water injection was used to hold back the safety valve flapper.
It was not possible to fish the straddle through the damaged safety valve so to regain integrity an inflatable bridge plug was set on eline below the packer; the tubing was punched above the packer after the well was circulated to clean fluid. A sand cushion was spotted on top of the inflate plug and, with coil positioned above the straddle, a balanced cement column was circulated via the tubing to the ‘A’ annulus, top of cement was planned to be above the straddle in tubing and Annulus.
Once the cement had set, 'A' annulus integrity was confirmed, coil tubing then cleared the cement to the top of the straddle. A smaller mill was then selected to mill a path through the cement and the straddle to the sand cushion and inflate plug. Milling the cement through the straddle went well, however as the mill broke through the cement the coil flexed and became stuck at the top of the inflate plug. The coil was eventually freed by pumping down the coil annulus and the inflate was lost in the well, injectivity to the well was tested and a reduced injection rate was achieved initially.
'A' annulus integrity to the tubing was reconfirmed after the milling operation and water injection recommenced. Within days water injection reached the expected rates.
Despite a troublesome repair, stretching over two interventions, this intervention can be considered a success - a water injector was successfully put back on line with well integrity intact.-. The pressure support provides increased production and extends life of field. No environmental issues occurred, and no people were hurt over the 47 days and 7824 man hours.
Abstract 19
CT-conveyed sand jetting perforation on deep tight gas well, treatment fluid selection and application perspective
Rafal Fryzowicz, BJ Services Company and Ton Maas, Kelco Oil Field Group
In the tight gas formations the perforation channel can be created by means of abrasive action. If possible to implement, such a method would leave clean cut hole in the liner without sharp edges and perforation tunnel in the formation free of crashed zone. The main advantage of sand jetting perforation lays in the cleaner and larger perforation channel. Perforations created with sand jetting technique usually display reduced near wellbore friction during hydraulic fracturing operations.
The preparations for sand jetting perforation operation in deep wells require proper selection of the carrier fluid. In deep horizontal wells sand laden slurry has to travel through small diameter coiled tubing adding up to the injection pressure at the pump. In order to lower pump pressure at the required treatment flow rates the sand is suspended in highly pseudoplastic fluid. The sand suspension in large suction lines and friction reduction in smaller CT are the main parameters required to complete the operation. The selection of proper carrier fluid maintaining both parameters at the bottom hole temperature is crucial to the job success.
This paper will discuss the testing of fluid systems from the perspective of the sand suspension and friction reduction capabilities along with the discussion of basic properties and parameters of the selected system. The findings from the tests will be verified by the actual sand jetting perforation operation on the North Sea deep tight gas well.
Abstract 20
Using MARS (Multiple Application Re-injection System) technology for improving oil recovery and reducing production risk.
Ian Donald & Ryan Sangster, Cameron MARS Production Systems
Developing the optimum subsea production system is not a straightforward process. Balancing technical, reservoir and production requirements against an economic profile, can lead to compromises at the project development stage which often leads to sub optimal production later in field life; moreover retrofitting sensor or performing fluid pumping operations can be very expensive and difficult in later stages of life of subsea wells.
Subsea production is expanding into deeper waters and more hostile environments. One technology that can help alleviate the dilemma between tackling the whole range of issues at project inception and the inevitable cost pressures is called MARS (Multiple Application Re-Injection System). MARS also facilitates IOR and EOR strategies in more mature basins, brownfield developments and greenfield projects.
By adopting a strategy for production that includes MARS technology, operators can build into a greenfield development plan, the capability to retrofit production enhancing technologies such as boosting or metering when they don?t have the full range of knowledge which can only be gained when production is initiated. MARS also allows new or emerging technology to be introduced when the operator is comfortable with its performance hence reducing project and initial production risk. This approach facilitates maximum flexibility with minimum outlay. The system can be installed at all stages of the life of the well to enable sensors and meter retrofit, fluid pumping operation from a standard supply vessel.
In Dec 2009, Chevron used MARS technology to enable rigless subsea scale squeeze on the Lobito Tomboco field in Angola. The technology was first deployed commercially in 2007, when BP installed two multiphase pumps on the already producing King field in the Gulf of Mexico. Other projects since then include manifold and tree mounted multiphase metering, fluid sampling, production boosting and fluid intervention on both existing production systems and new projects.
MARS is being used in the North Sea, Gulf of Mexico and West Africa.
Abstract 21
Fiber optic enabled coiled tubing optimizes well interventions in the Val D’ Agri field in Italy
Tiani Alessandro and Angelo Bruini, Eni; Cevallos Antonio, Carreno Nestor and Adil Abdur Rahman, Schlumberger
The Val D’ Agri field is located in the south of Italy. The wells in this field are producing from multiple zones in a variety of natural fracture carbonates rocks characterized by long horizontal drains with presence of heavy asphaltenes, high H2S and close proximity of water and oil contact points. The produced oil displays a range of API gravities most commonly varying from 32º to 37º.
The main job types identified in this field are clearly associated with pumping applications as a common ways of well intervention. Coiled Tubing operations such as wellbore cleanouts with solvents, acid stimulations or nitrogen kick-off are common ways of intervention where treatments are most often designed with assumed values or very limited information related to bottomhole pressure and temperature.
A novel technology that uses fiber-optic enabled coiled tubing and a bottom hole assembly that collects point measurements of downhole Pressure (internal or external) – Temperature – Casing Collar Log (PTC). An added feature of the non-intrusive fiber optic techonology is its ability to measure a Distributed Temperature Survey (DTS) – a continous temperature log along the coiled tubing which enables measurements available at surface in real time.
Most of the current designs for wellbore cleanouts through coiled tubing in Val D’ Agri wells, particularly for those with liner completion in the horizontal drains, require the spotting of the solvents in a particular interval along the liner track where many coiled tubing cycles in and out of the hole is required for an effective cleanout. In conventional coiled tubing interventions, accurate depth is uncertain and subjected to discrepancy due inherent imprecisions involved during operation such as errors of reference, procedure, surface measurement and due to downhole deformation of the coiled tubing.
A DTS log takes important meaning in horizontals drains where geothermal temperature along the horizontal section doesn’t provide any measurable thermal response, however Joule-Thomson effect can cause a flow-related change in the well-fluid temperature that can be interpreted to indicate flowing intervals and flow contributions. Joule-Thomson effect in horizontal drains is relatively small, necessitating the highest possible resolution in the acquisition of the temperature data.
The application of DTS system in Val D’ Agri field provided critical information required to assist in the decision making process of coiled tubing services for treatment diversion. The Identification of significant inflows along the productive zones simultaneously with proper thermal interpretation of the DTS log gave indications of hydrocarbon entry points along the wellbore providing the confidence to act decisively in zones that need more treatment emphasis and subsequent improving well performance.
A total of 3 wells were treated by utilizing this novel system where the results exceeded expectations sets with earlier treatments. Furthermore, monitoring real time bottom hole data during intervention significantly improved the job efficiency and treatment effectiveness as a result of parameters optimization such accurate depths, injection rates, treatment volumes, coiled tubing speed, as well as reducing risks where issues can be corrected as they are encountered.
Abstract 22
A production and workover unit based on a monohull floater
Goof Zijderveld and Leen Poldervaart of GustoMSC and SBM Offshore
Given the high day rates of deepwater drilling rigs, the overall well maintenance costs for subsea wells are a significant part of the total costs for deepwater field developments resulting in premature abandonment of failed but originally productive wells
Recent drilling and completion technologies have resulted in improved reliability, higher production levels and an increase in recovery for individual wells. This has allowed for an optimization of the well system design and number of subsea wells installed in deepwater areas. A cost-effective access to the well and regular well maintenance during the field life are considered key issues for optimal reservoir management, which allows for accelerated production, an increase in Ultimate Recoverable Reserves (URR) and significant savings in operating costs during the field life (e.g. optimal design of process facilities).
A Floating Production and Workover Unit (FPWU), allowing for simultaneous production and workover operations from a large monohull floater has been developed.
Concept Overview
Based on a large monohull, the Floating Production and Workover Unit (FPWU) is designed for worldwide applications. The FPWU is kept on station via a fully passive station keeping system, an internal turret system or, spread moored.
The FPWU provides a direct vertical access to a number of subsea wells clustered directly under the vessel/turret, allowing for an optimal reservoir management over the field life. A deepwater riser system connects the main (subsea) well system, to the turret system or riser bay of the surface facility. The produced fluids are transferred via a swivel or directly to the process facilities located on the main deck of the freely weathervaning or spread moored vessel.
The vessel has crude oil storage capacity and produced oil is directly exported from the FPSO vessel to a shuttle tanker.
The FPWU design is based on three existing technologies:
1. Floating production system based on a monohull floater: FPSO and FSO systems have proven to be technically sound and economically attractive solutions for a range of field developments worldwide.
2. Large-diameter turret design: Based on a bogie system, a large-diameter turret has been used for the Schiehallion FPSO, which has been in operation since 1998 offshore West Shetland.
3. If environmental conditions allow, a spread moored FPSO approach can be utilized.
4. Workover operations from floating offshore structures: Workover operations and equipment arrangement on the FPWU is similar to the equipment used on drillships and drilling & production semis.
In case of a turret based system, from the FPWU, light and medium well interventions can be performed, based on rigless well intervention techniques [Ref. 4] including wireline and Coiled Tubing (CT) applications. A dedicated well intervention riser can be deployed through the large-diameter turret. On the turret structure and the vessel main deck sufficient space is available to install the workover equipment.
The large-diameter turret enables segregating the two main functional areas on top of the turret structure:
* On one side of the turret, well streams are manifolded and linked to the centrally located swivel, which ensures the fluid transfer from the turret structure to the main process facilities on the vessel main deck.
* The other half of the large-diameter turret structure provides space to install workover equipment (packages) as per requirements.
For safety reasons, both areas are clearly separated by a wall.
In case of a spread moored system the FPWU is fitted with a fixed installation and a moonpool for intervention operations
Compared to alternative deepwater solutions the FPWU has the potential of improving overall project economics due to:
* Low CAPEX for surface facility
* Reduction in well intervention costs (compared to other subsea well systems)
* Accelerated and improved recovery
* Short delivery schedule for surface facility and consequently early production.
In addition to above, some alternate means of well intervention will also be addressed.
Abstract 23
New higher strength coiled tubing developed to extend coiled tubing operating envelopes
W. D. Van Arnam, SPE, Dale Klink, SPE, and Jack Tackitt, SPE, Quality Tubing
A new high strength coiled tubing grade has been developed to address the need for improved axial strength, better fatigue performance and the ability to function at higher operating pressures. Tubing has been successfully made using existing manufacturing methods. The initial testing indicates the tubing has high strength with good ductility. Fatigue testing shows superior performance to existing grades of tubing in both cycles to failure and diametrical growth. The paper will review the mechanical properties and fatigue test results of several strings manufactured. The material is weldable and the results for bias, longitudinal tube and tube to tube welding will also be reviewed.
This development project was under taken when coiled tubing service companies and operators defined several areas where existing coiled tubing is not considered capable of performing desired tasks. These areas include carrying heavier payloads to the well perforation zone and working in today’s increasingly longer horizontal sections. Along with these conditions has come the need to operate with higher pumping pressures. The paper will illustrate how this new grade will be utilized to extend coiled tubing’s operating envelopes.
Abstract 24
The new API standard for coiled tubing, and results from the SR 37 assessments
Presenter: Roderic K Stanley
Company: itRobotics Stafford, TX, and International Oilfield Services, Lafayette, LA, USA.
The development and contents of API 5ST, the manufacturing standard for coiled tubing in the grade range CT70-CT110 will be discussed. The standard contains a supplementary requirement for final inspection after hydrostatic test (SR 37), which is now being performed on strings considered critical by purchasers. An assessment tool (wall thickness, diameter, ovality, imperfections) has been developed that permits the NDE reference indicators in 5ST to be used to set the sensitivity of imperfection channels of the tool. The same took can then be used to track strings through their life-time. Some recent results of both new, and in service assessments will be presented.
Abstract 25
Coiled tubing development for subsea wells
Eamonn McGennis, Helix Well Ops
This presentation will look at the systems and equipment developed to deploy coiled tubing into subsea wells. The first coiled tubing work off a mono-hull vessel in subsea wells was done in 1995. Since this time coiled tubing has not been used off intervention vessels as much had to be done to improve on the effectiveness of operations offshore. Using the lessons learnt from the early subsea work a new purpose built coiled tubing handling and deployment systems has been designed and built for use off the most recently delivered subsea well intervention vessel the Well Enhancer. This purpose built well intervention vessel entered service in November 2009 and the presentation will review the systems developed to deploy coiled tubing into subsea wells. The presentation will also review the first planned job and the work done over the summer with the new equipment.
Abstract 26
Application of heavy duty wireline fishing techniques to successfully retrieve well obstructions
Shell UK and Ralph Macaulay, John Vincent - Weatherford International
This case study will examine the removal of an obstruction on Well BC-14 on the Shell operated Brent Charlie platform. Obstructing access to the well was a 3.6-in Wireline roller bogie cutter, 6600ft of 0.125-in supa 75 wire, slickline tool string and a PES 4-1/2-in HE-3 bridge plug complete with PES DPU and RO setting tool. The fish had been in the well for three and a half years with the condition of the wire lost down hole undetermined. In addition to this the well had tubing to annulus communication. The operational objective was to remove all obstructions from the well in order to allow access to set a plug and secure well integrity.
This paper will detail the operation while highlighting limiting factors and challenges overcome as well as demonstrate how the use of specialist Heavy Duty Wireline Fishing equipment and downhole tools, in conjunction with detailed planning, provided a cost effective alternative to traditional and costly workover operations.
The successful utilisation of Heavy Duty Wireline Fishing techniques were applied with no lost time or safety incidents and resulted in the complete recovery of all well obstructions, allowing Wellservices to successfully plug the well and regain well integrity
Abstract 27
Heavy duty wireline fishing techniques utilised to successfully retrieve well obstructions through the provision of a cost effective solution allowing for the continuation of workover operations
Shell UK and Ralph Macaulay, John Vincent - Weatherford International
This case study will examine the removal of obstructions from Well BC-21 on the Shell operated Brent Charlie platform. A 7-in Posi Set Thru Tubing Bridge Plug MBPT had been lost in the well some eight years previously. The model and type of plug could not be confirmed from either well reports or from manufacturer / supplier records. To further complicate matters the 7-in plug type was non-retrievable once set and did not have a fish neck for retrieval purposes, with the manufacturer stating that removing this type of plug from the well would require drilling, milling or wash over operations. Additionally, subsequent attempts to fish had resulted in various other assemblies being left in the well. The operational objective was to clear the well of all obstructions in preparation for workover.
This paper will detail the operation while highlighting limiting factors and challenges overcome as well as demonstrate how the use of specialist Heavy Duty Wireline Fishing equipment and downhole tools, in conjunction with detailed planning, provided a cost effective alternative to traditional and costly milling operations. The following obstructions were retrieved from the well; junk catcher, 2 x 5.72-in TRO plugs, Big Bore Dummy insert Valve, Upper Straddle, 7-in Posi Set Plug and a Lower gas lift straddle complete with gas injection head.
A total of 73 wireline runs were carried out over a 19 day period using Heavy Duty Wireline Fishing techniques, resulting in the successful retrieval of the plug and all other fish, thus allowing the drilling team access to the well to complete the work over. No lost time or safety incidents occurred during this operation
Abstract 28
Sixteen wells abandoned without a rig – case study / Title to be confirmed
Neringa Dugnaite, Halliburton
As North Sea production declines a new and enormous decommissioning market is emerging with the numbers of wells in the North Sea to be abandoned exceeding 4000 in recent years.
Drilling rigs are normally best suited to carry out well decommissioning work but a different approach was carried out in 2009 – 2010 for an operating company in the Southern North Sea (SNS). Sixteen wells on three separate Normally Unmanned Installations (NUI’s) were all abandoned without a rig. A Self Elevating Workover Platform (SEWOP) which housed equipment, crew and resources was used instead.
The majority of the work was coordinated and carried out by a single service company with the capability to perform multiple services such as slickline, e-line, explosives, perforating, logging, completions, special tools, cementing, mud, pumping, coiled tubing and hydraulic workover.
A dedicated onshore engineering and project management team from a single service company along with a multi-skilled offshore team delivered results which exceeded the customers’ expectations and may not have been possible with the involvement of multiple service companies.
This presentation details the entire operation from the choice of products and services used in different scenarios to the innovation that was applied to benefit both the customer and service company.
Abstract 29
Increased production with through tubing remedial sand screen deployment using inflatable straddle conveyed on e-line tractor
Richard McKee, Baker Hughes
A North Sea client had a well in which they were aiming to perforate and produce from a new shallower zone. This required the placement of Sand Screens without shutting off the lower producing zone or pulling the completion.
A Through Tubing Remedial Sandscreen Straddle solution was devised where 200 ft of BakerWrap XP screens were deployed in a multi trip system. 4 x 50 ft screen runs made up of 20 ft and 30 ft sections, connected on surface by the Baker Atlas SnapScreen Connector (2009 ICoTA Innovation award) were deployed and set between 4.25” Permanent Through Tubing Inflatable Straddle upper and lower packers. The packers provided the anchor for the screens and the seal between the new and existing perforations. Due to the well geometry and the rig set up the system was deployed on eline tractor with each run in the well disconnected via the operation of the BOT Electric Wireline Setting Tool. Thru Tubing SnapLatches and Receptacles were used to connect each of the runs down hole. Onshore tests were carried out to determine the feasibility of the operation before execution.
Abstract 30
Vacuum cleaning gas wells with concentric coiled tubing - Ravenspurn North NUI heavy duty wellwork project
Ann Davies – BP
Heavy Duty Wellwork project targets a number of wells in the lower recover factor area of Ravenspurn North (under 40%) centred around the ST3 unmanned installation. Approximately 50% of these wells are shut in due to proppant, sand and liquid fill.
Concentric coiled tubing complete with ‘Sand Vac’, ‘Well Vac’ and jetting technology was used to clean the wells of sand, proppant and liquid. Post cleanout the wells would be fitted with ~1,000ft of 2-3/8” FJL tubing (deployed on concentric coiled tubing with a packer) to extend the tubing landing depth to top perforations. Furthermore, to install the tailpipe, two profile nipples needed to be milled out with the concentric coil. Planning of these operations required good teamwork between all vendors involved.
To achieve a well intervention campaign on ST3 NUI has been challenging. Detailed planning of positioning the equipment and the deck loading had to be conducted. Shuttling the crew from onshore to offshore each day and night to allow 24 hour operations to continue brought daily logistical challenges. The crane limit of 11Te meant that the 42Te concentric coiled tubing reel had to be boat spooled onto the platform. The rig up also had to allow for deployment of both 2” concentric coiled tubing and 2-3/8” jointed FJL tubing.
Overall, this campaign is extremely challenging, very exciting and is pushing the boundaries of technology. This has been the first application of concentric coil in North Sea industry, and the deepest TVD depth that Sand Vac technology has been deployed worldwide. Successful results in Phase 1 of Heavy Duty Wellwork will open up opportunities to target a number of Ravenspurn wells which will hopefully defer the abandonment of the field, and increase access to Southern Gas reserves
Abstract 31
Rigless separation of seized well flanges
Alastair MacDonald and Guy Bromby, ThinJack
Problems in safely separating flanges seized together are caused either by rust between the flange studs and their holes or friction from the flange seals. These difficulties delay hydrocarbon production and well intervention programmes resulting in costly standby of other equipment and people.
This “warts and all” paper describes the science and operations of a flange separation system to overcome the rust and friction. ThinJack™ is a steel envelope approximately 2mm thin, designed to fit API6A specification flanges. The steel envelopes are inserted between the flange surfaces to be separated and then hydraulically inflated at pressures up to 36,250 psi. (2500 bar). This results in both flange separation and stud removal from the flange bolt holes, at the same time. The forces generated amount to hundreds of tonnes and result in dependable, faster and safer flange separation, when compared with conventional techniques.
Applications include separating corroded and stuck flanges and bonnets on well heads and christmas trees.
Examples are discussed of flanges separated for Apache in the North Sea, Sonangol in Angola, Shell in the Netherlands, ExxonMobil in the Gulf of Mexico and Woodside in Australia. Analysis includes: A) forces generated, compared with the flange gap and the binding forces of the rust B) time used and saved C) earlier hydrocarbon production and D) overall cost savings compared with other techniques. Problems encountered and overcome are discussed.
This paper describes successful applications of a novel technology and could be included in the following programme topics:
• Intervention equipment development
• Intervention techniques and practices
• New technology and alternative solutions
• Well completion and related intervention tools
• Safety innovations
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