A new downhole machining system has been developed for lightweight intervention applications to remove wellbore obstructions and stuck valves, combining the precision of real-time bit position measurement with the power of push-pull forces up to 40,000 lbf. This tool builds on existing hardware from proven milling and shifting services, with added software features for advanced automation and control. This paper describes the new machining system and benefits for the operator to enable a reliable and robust contingency machining service. Conventional wireline milling tools use a tractor tool for weight-on-bit and torque reaction. These tractor-based milling systems can be efficient for removing obstructions over a long interval, but they are not ideal for milling hard metal targets. For example, a nipple milling operation might require many hours to mill, during which time the operator has no indication that the milling operation is progressing as planned since the tractor does not provide any measurement of milling progress. The new machining system provides the operator with a real-time measurement of milling progress with resolution down to 1/100-in. to quickly diagnose and correct any problems due to bit damage, engagement with the target, or cuttings accumulation. For known targets of multiple materials or interrupted geometry, or for bits with staged cutting features, the direct measurement of bit position enables automatic machining programs that can autonomously execute a predefined sequence of cutting parameters (weight, speed, and torque) that change with measured bit position. The machining progress and quality indicators are displayed in real time at surface using a graphic interface showing the machining target and current bit position. The machining tool uses the same anchor and linear actuator modules from wireline shifting service tools, combined with the same rotary motor and gearing modules from wireline milling service tools. Torque from the bit is transferred across the linear actuator module using a sleeve that is keyed above and below the piston. Both the linear actuator hydraulic motor and the rotary motor are equipped with rotor position and torque feedback and powered by a downhole inverter for maximum power efficiency, precise control of hydraulic pressure and bit position, and reverse operation for stall prevention and recovery. Test data are shared in this paper to compare the performance of the new machining tool with a high-performing tractor-based milling service tool. Examples are given for both isolation valve machining and nipple machining.
{"title":"High-Precision Automated Downhole Machining Tool with Real-Time Bit Position Measurement","authors":"Kyle Wiesenborn, R. Feliu","doi":"10.2118/212875-ms","DOIUrl":"https://doi.org/10.2118/212875-ms","url":null,"abstract":"\u0000 A new downhole machining system has been developed for lightweight intervention applications to remove wellbore obstructions and stuck valves, combining the precision of real-time bit position measurement with the power of push-pull forces up to 40,000 lbf. This tool builds on existing hardware from proven milling and shifting services, with added software features for advanced automation and control. This paper describes the new machining system and benefits for the operator to enable a reliable and robust contingency machining service.\u0000 Conventional wireline milling tools use a tractor tool for weight-on-bit and torque reaction. These tractor-based milling systems can be efficient for removing obstructions over a long interval, but they are not ideal for milling hard metal targets. For example, a nipple milling operation might require many hours to mill, during which time the operator has no indication that the milling operation is progressing as planned since the tractor does not provide any measurement of milling progress. The new machining system provides the operator with a real-time measurement of milling progress with resolution down to 1/100-in. to quickly diagnose and correct any problems due to bit damage, engagement with the target, or cuttings accumulation. For known targets of multiple materials or interrupted geometry, or for bits with staged cutting features, the direct measurement of bit position enables automatic machining programs that can autonomously execute a predefined sequence of cutting parameters (weight, speed, and torque) that change with measured bit position. The machining progress and quality indicators are displayed in real time at surface using a graphic interface showing the machining target and current bit position.\u0000 The machining tool uses the same anchor and linear actuator modules from wireline shifting service tools, combined with the same rotary motor and gearing modules from wireline milling service tools. Torque from the bit is transferred across the linear actuator module using a sleeve that is keyed above and below the piston. Both the linear actuator hydraulic motor and the rotary motor are equipped with rotor position and torque feedback and powered by a downhole inverter for maximum power efficiency, precise control of hydraulic pressure and bit position, and reverse operation for stall prevention and recovery.\u0000 Test data are shared in this paper to compare the performance of the new machining tool with a high-performing tractor-based milling service tool. Examples are given for both isolation valve machining and nipple machining.","PeriodicalId":433466,"journal":{"name":"Day 1 Tue, March 21, 2023","volume":"9 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-14","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"130501618","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Leaking and compromised liner tops have been a common ongoing problem in the oilfield. A poor cement job around the liner top can not only lead to gas or fluid migration from non-productive zones during the lifecycle of the well but can also severely limit remediation abilities by resulting in lower than desired frac pressures if the leak is substantial. The existing solution which involves squeezing cement is not only notoriously difficult but is also unreliable, time consuming, equipment heavy and fails to provide a gas tight seal if needed. This has over the years resulted in a very high number of leaking liner tops, a problem which needs a quick and reliable solution.
{"title":"Alternative Approach to Liner Top Repairs","authors":"P. Carragher, D. Talapatra, Pedro Antonio Vergel","doi":"10.2118/212886-ms","DOIUrl":"https://doi.org/10.2118/212886-ms","url":null,"abstract":"\u0000 Leaking and compromised liner tops have been a common ongoing problem in the oilfield. A poor cement job around the liner top can not only lead to gas or fluid migration from non-productive zones during the lifecycle of the well but can also severely limit remediation abilities by resulting in lower than desired frac pressures if the leak is substantial. The existing solution which involves squeezing cement is not only notoriously difficult but is also unreliable, time consuming, equipment heavy and fails to provide a gas tight seal if needed. This has over the years resulted in a very high number of leaking liner tops, a problem which needs a quick and reliable solution.","PeriodicalId":433466,"journal":{"name":"Day 1 Tue, March 21, 2023","volume":"36 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-14","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"129956937","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
N. Baklanov, Xuedong Yang, Maxim Klyuzhev, B. Durand
A semi-autonomous wireline tractor solution for casedhole applications enabling navigation through complex restrictions with minimal operator interaction in absence of digital telemetry is presented. The robotic conveyance technology provides a foundation for applications where programming of tractoring behaviors is available to field personnel as a part of the job design. Digital telemetry may not be available for wireline tractor tools. A conveyance system with programmable behaviors allows downhole navigation when conventional telemetry is nonexistent or has prohibitively low bandwidth or a protocol conflict, which is relevant in configurations with third-party tools. The presented control technology utilizes downhole on-board measurements with tracking and decoding of head voltage waveforms where electrical power is supplied by the surface system. Voltage is set by an operator to fall into one of several predefined bands representing specific tool commands that trigger a set of robotic sequences. The logging cable can be freed to carry a high-frequency communication signal to payload tools while powering both the tractor and its payload. Although the tractor does not have feedback through its telemetry data, tractor operational condition can be derived from the variations of electrical current measured at surface. A head voltage stabilization system along with a load calibration method compensates voltage fluctuations due to load changes and losses in the logging cable. An advanced signal-processing algorithm implemented in downhole embedded software quantizes denoised voltage and reliably maps it to operational bands, effectively eliminating transient processes resulting from high-power jobs. The voltage estimation technique supports a finite set of commands to be interpreted by the downhole tools and to activate control logic implemented as scripted state machines with a core based on the deterministic finite automaton concept. Behaviors scripted and parametrized by an operator in custom metalanguage use a dictionary of actions and conditions provided by the embedded software that runs the tools. Controllers may be designed and put into action by nonprogrammers to solve restriction navigation needs for a known well completion. The availability of design and simulation software aids job planning. Multiple tractor configurations with individually controlled arms were successfully tested at locations in the USA and Eurasia, with and without third-party tools with their own telemetry. Reliable restriction navigation using preprogrammed behaviors controlled by voltage levels has been demonstrated. The design opens development opportunities for other semi-autonomous downhole applications. Run-time pattern recognition of electrical current in the software enables further automation of the surface power system to drive the downhole navigation, detect and respond to anomalies, and reliably manipulate voltage transitions. The presented technolog
{"title":"Wireline Tractor System with User Programmable Behaviors for Semi-Autonomous Restriction Navigation","authors":"N. Baklanov, Xuedong Yang, Maxim Klyuzhev, B. Durand","doi":"10.2118/212876-ms","DOIUrl":"https://doi.org/10.2118/212876-ms","url":null,"abstract":"\u0000 A semi-autonomous wireline tractor solution for casedhole applications enabling navigation through complex restrictions with minimal operator interaction in absence of digital telemetry is presented. The robotic conveyance technology provides a foundation for applications where programming of tractoring behaviors is available to field personnel as a part of the job design.\u0000 Digital telemetry may not be available for wireline tractor tools. A conveyance system with programmable behaviors allows downhole navigation when conventional telemetry is nonexistent or has prohibitively low bandwidth or a protocol conflict, which is relevant in configurations with third-party tools. The presented control technology utilizes downhole on-board measurements with tracking and decoding of head voltage waveforms where electrical power is supplied by the surface system. Voltage is set by an operator to fall into one of several predefined bands representing specific tool commands that trigger a set of robotic sequences.\u0000 The logging cable can be freed to carry a high-frequency communication signal to payload tools while powering both the tractor and its payload. Although the tractor does not have feedback through its telemetry data, tractor operational condition can be derived from the variations of electrical current measured at surface. A head voltage stabilization system along with a load calibration method compensates voltage fluctuations due to load changes and losses in the logging cable. An advanced signal-processing algorithm implemented in downhole embedded software quantizes denoised voltage and reliably maps it to operational bands, effectively eliminating transient processes resulting from high-power jobs. The voltage estimation technique supports a finite set of commands to be interpreted by the downhole tools and to activate control logic implemented as scripted state machines with a core based on the deterministic finite automaton concept. Behaviors scripted and parametrized by an operator in custom metalanguage use a dictionary of actions and conditions provided by the embedded software that runs the tools. Controllers may be designed and put into action by nonprogrammers to solve restriction navigation needs for a known well completion. The availability of design and simulation software aids job planning. Multiple tractor configurations with individually controlled arms were successfully tested at locations in the USA and Eurasia, with and without third-party tools with their own telemetry. Reliable restriction navigation using preprogrammed behaviors controlled by voltage levels has been demonstrated.\u0000 The design opens development opportunities for other semi-autonomous downhole applications. Run-time pattern recognition of electrical current in the software enables further automation of the surface power system to drive the downhole navigation, detect and respond to anomalies, and reliably manipulate voltage transitions. The presented technolog","PeriodicalId":433466,"journal":{"name":"Day 1 Tue, March 21, 2023","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-14","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"130119044","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
H. Alshammari, S. Baki, Zahaezuani Rafiq Hamidon, S. Kurniadi, Abdullah Alzamil, Zeyad Habiballah
The requirement of tapping new hydrocarbon reserves has pushed the Middle East region to develop its unconventional resources. During the development, longer laterals are drilled to achieve more stages and increase well productivity. This generates more complex intervention activities, including the post-fracturing plug millout with coiled tubing (CT). This study outlines comprehensive evaluation of frac plug milling practices integrated with designing and execution of CT operations to improve overall milling efficiency for these unconventional horizontal wells. Milling optimization was obtained by tackling key enablers of higher efficiency. First, the CT string was precisely engineered to serve the well trajectory and completion size. The tapered wall thickness configuration was strategically planned to maximize stiffness at the highly deviated section while reducing weight on the long horizontal lateral. Plug selection and placement strategy were also meticulously planned to configure the best combination of composite and dissolvable plugs. Since different plug types behave differently during milling, the millout strategy was tailored specifically for each type and their actual downhole environment. The new engineered CT design, coupled with an extended reach tool (ERT), was proven effective in overcoming reach challenges across the long lateral while maintaining sufficient weight-on-bit (WOB) to mill the plugs. The ERT was also observed to enhance milling action due to the vibrations it generated. Those improvements led to faster and smoother operations, resulting in 70% reduction of operating time compared to the baseline established prior to the start of the project. The comprehensive plug placement strategy and better understanding of different plugs behavior in different environments further improved the milling efficiency, as the average milling time per plug was reduced by 80%. Additionally, the reduction in operating time improved the environmental sustainability of the project, as carbon emissions from the CT unit were reduced. The comprehensive engineering design and plug selection strategy delivers significant improvements in millout efficiency. Implementation of key enablers led to performance increase, better resource utilization, and further cost optimization. This achievement also aligns with initiatives to reduce the impact of oil and gas operations on the environment, thus contributing to the goal of achieving net-zero in carbon emission.
{"title":"Improving Milling Efficiency in HP/HT Unconventional Field by Comprehensive Engineering Design and Strategic Planning of Fracturing Plugs","authors":"H. Alshammari, S. Baki, Zahaezuani Rafiq Hamidon, S. Kurniadi, Abdullah Alzamil, Zeyad Habiballah","doi":"10.2118/212938-ms","DOIUrl":"https://doi.org/10.2118/212938-ms","url":null,"abstract":"\u0000 The requirement of tapping new hydrocarbon reserves has pushed the Middle East region to develop its unconventional resources. During the development, longer laterals are drilled to achieve more stages and increase well productivity. This generates more complex intervention activities, including the post-fracturing plug millout with coiled tubing (CT). This study outlines comprehensive evaluation of frac plug milling practices integrated with designing and execution of CT operations to improve overall milling efficiency for these unconventional horizontal wells.\u0000 Milling optimization was obtained by tackling key enablers of higher efficiency. First, the CT string was precisely engineered to serve the well trajectory and completion size. The tapered wall thickness configuration was strategically planned to maximize stiffness at the highly deviated section while reducing weight on the long horizontal lateral. Plug selection and placement strategy were also meticulously planned to configure the best combination of composite and dissolvable plugs. Since different plug types behave differently during milling, the millout strategy was tailored specifically for each type and their actual downhole environment.\u0000 The new engineered CT design, coupled with an extended reach tool (ERT), was proven effective in overcoming reach challenges across the long lateral while maintaining sufficient weight-on-bit (WOB) to mill the plugs. The ERT was also observed to enhance milling action due to the vibrations it generated. Those improvements led to faster and smoother operations, resulting in 70% reduction of operating time compared to the baseline established prior to the start of the project. The comprehensive plug placement strategy and better understanding of different plugs behavior in different environments further improved the milling efficiency, as the average milling time per plug was reduced by 80%. Additionally, the reduction in operating time improved the environmental sustainability of the project, as carbon emissions from the CT unit were reduced.\u0000 The comprehensive engineering design and plug selection strategy delivers significant improvements in millout efficiency. Implementation of key enablers led to performance increase, better resource utilization, and further cost optimization. This achievement also aligns with initiatives to reduce the impact of oil and gas operations on the environment, thus contributing to the goal of achieving net-zero in carbon emission.","PeriodicalId":433466,"journal":{"name":"Day 1 Tue, March 21, 2023","volume":"84 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-14","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124142464","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
One of O&G operator in Indonesia is scheduled to have a re-entry and drilling campaign at their deepwater field. The re-entry program objectives were to cut 5-1/2", 17#, 13Cr-L80 tubing and POOH existing upper completion prior P&A operation. Due to the well condition the chosen cut depth was at high inclination and multiple control lines need to be severed. A cutter with new design machining arm shaped like tiger claw was chosen to perform the cut. This operation was an outstanding achievement and the first time for deepwater in the region. A conventional way of tubing cut is putting the tubing in tension to prevent cutting blades got pinched and increase the chance of successful cut. However, the challenge for tubing cutting at this well was not only to cut the multiple control lines but also tubing hanger was not preferred to be unlatched prior tubing cut. The mechanical cutter should be able to cut under compression and also reach control lines with total OD of 6.916". Mechanical cutter with new design tiger claw blade was chosen due to its ability to cut the tubing under compression and also the blade arms could expand increases the cutting range to 7.2" guaranteeing continuation cutting beyond tubular OD through the multiple control lines. As this will be the first time in Indonesia, a SIT was performed in two conditions, under compression and neutral, with results confirming the cutter was able to cut tubing and multiple control lines. The cutter was deployed using e-line with tractor conveyance due to high degree inclination and positioned 1m below the tubing coupling to ensure the control lines were still in tension as it was close to the cable clamp. The new machining arm technology produces a grinding effect to cut through the tubing and as it expanded reaching the control lines, the blades keep grinding the tubing body and scored the control lines. After 129mins effective cutting time and confirmed with the circulation from annulus to tubing, it was decided to stop and POOH the cutter. When the cutter at the surface, it was measured that the blade had expanded, and operation continued to unlatch tubing hanger and POOH upper completion. The tubing was cut with a clean and smooth surface with control lines sheared at cutting depth. With the newly designed cutting elements, enabling a safe and efficient cutting operation. This solution eliminates the risks of unlatching the TH and put tubing in tension, the cost of rig time and ensuring no interruption to the well program. Operational details, including job planning and lessons learned will be discussed in the paper
{"title":"First Successful Mechanical Cutter Cut Tubing Under Compression Including Three Different Types of Control Lines","authors":"Recia Karina Melly, Surya Putra Sri Sutama","doi":"10.2118/212891-ms","DOIUrl":"https://doi.org/10.2118/212891-ms","url":null,"abstract":"\u0000 One of O&G operator in Indonesia is scheduled to have a re-entry and drilling campaign at their deepwater field. The re-entry program objectives were to cut 5-1/2\", 17#, 13Cr-L80 tubing and POOH existing upper completion prior P&A operation. Due to the well condition the chosen cut depth was at high inclination and multiple control lines need to be severed. A cutter with new design machining arm shaped like tiger claw was chosen to perform the cut. This operation was an outstanding achievement and the first time for deepwater in the region.\u0000 A conventional way of tubing cut is putting the tubing in tension to prevent cutting blades got pinched and increase the chance of successful cut. However, the challenge for tubing cutting at this well was not only to cut the multiple control lines but also tubing hanger was not preferred to be unlatched prior tubing cut. The mechanical cutter should be able to cut under compression and also reach control lines with total OD of 6.916\". Mechanical cutter with new design tiger claw blade was chosen due to its ability to cut the tubing under compression and also the blade arms could expand increases the cutting range to 7.2\" guaranteeing continuation cutting beyond tubular OD through the multiple control lines.\u0000 As this will be the first time in Indonesia, a SIT was performed in two conditions, under compression and neutral, with results confirming the cutter was able to cut tubing and multiple control lines. The cutter was deployed using e-line with tractor conveyance due to high degree inclination and positioned 1m below the tubing coupling to ensure the control lines were still in tension as it was close to the cable clamp.\u0000 The new machining arm technology produces a grinding effect to cut through the tubing and as it expanded reaching the control lines, the blades keep grinding the tubing body and scored the control lines. After 129mins effective cutting time and confirmed with the circulation from annulus to tubing, it was decided to stop and POOH the cutter. When the cutter at the surface, it was measured that the blade had expanded, and operation continued to unlatch tubing hanger and POOH upper completion. The tubing was cut with a clean and smooth surface with control lines sheared at cutting depth.\u0000 With the newly designed cutting elements, enabling a safe and efficient cutting operation. This solution eliminates the risks of unlatching the TH and put tubing in tension, the cost of rig time and ensuring no interruption to the well program. Operational details, including job planning and lessons learned will be discussed in the paper","PeriodicalId":433466,"journal":{"name":"Day 1 Tue, March 21, 2023","volume":"63 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-14","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"126254624","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
D. Troup, Gladwin Correia, S. Murchie, Stian Løvås, K. Nasr
The ability to intervene in extreme extended reach wells using conventional technology has lagged behind the ability to drill and complete them. This paper intends to describe how the physical properties inherent in carbon composite materials provide a means of deploying logging tools into such a well in combination with a high-performance tractor, and to document a case study where a total depth of 40,600 feet (ft) was achieved against a production flow of 6,500 barrels of oil per day (BOPD). Extending the distance that a toolstring may be conveyed into a horizontal well by means of tractoring devices is well established. The medium for the conveyance becomes the critical component of the system to both maximise the ultimate depth achievable and to ensure safe retrieval. Low friction, low weight and high strength of the rod all combine to reduce required tractor loading and ensure safe recovery. The rod rigidity confers exceptional depth accuracy and removes the potential of tool-lift at high production rates, allowing logging under conditions that are truly representative of commercial well operation. A well that was drilled to a depth in excess of 40,000ft measured depth, with a trajectory designed to maximise the contact between wellbore and reservoir, was completed with a limited entry liner. A total of 37 compartments with lengths between 700ft and 900ft were separated with swell packer assemblies along a horizontal section of 25,000ft. Critical information about the production flow, including toe/heel balance, had been unavailable because of the limitations imposed by the available intervention methods. The intervention was designed to fully exploit the physical properties of the carbon composite rod in combination with the most efficient in-well controlled tractoring technology available, and aimed to reach deeper than 40,000ft. Simulations based on previous experience showed that this depth would be achievable with the tractor chosen and further that this could be achieved even with the well flowing at rates of over 5,000BOPD. This meant that deferred production could be minimised along with waiting periods for flow stabilisation. The intervention was successfully concluded in a single operation, gathering production data from as deep as 40,600ft. Performance of both rod and tractor aligned with planning simulations with significant margin, indicating further performance enhancements in reach being readily achievable. Drilling of such extended reach wells from existing islands will reduce well counts, accelerate development and increase oil recovery by unlocking reserves from the tight rock and areas that are currently unreachable from existing islands and wellhead platforms. Technology solutions like carbon composite rod and high-performance tractors enable the operators to acquire production logs & perform well services effectively to maintain the life cycle of extended reach wells inaccessible with conventional solutions.
{"title":"Carbon Composite Technologies Combine with the Latest High Performance Downhole Tractor to Gather Production Data from Deeper than Ever Before, Logging 32 Compartments Over 25,000ft Horizontally to a Total Depth of 40,600ft","authors":"D. Troup, Gladwin Correia, S. Murchie, Stian Løvås, K. Nasr","doi":"10.2118/212917-ms","DOIUrl":"https://doi.org/10.2118/212917-ms","url":null,"abstract":"\u0000 The ability to intervene in extreme extended reach wells using conventional technology has lagged behind the ability to drill and complete them. This paper intends to describe how the physical properties inherent in carbon composite materials provide a means of deploying logging tools into such a well in combination with a high-performance tractor, and to document a case study where a total depth of 40,600 feet (ft) was achieved against a production flow of 6,500 barrels of oil per day (BOPD).\u0000 Extending the distance that a toolstring may be conveyed into a horizontal well by means of tractoring devices is well established. The medium for the conveyance becomes the critical component of the system to both maximise the ultimate depth achievable and to ensure safe retrieval. Low friction, low weight and high strength of the rod all combine to reduce required tractor loading and ensure safe recovery. The rod rigidity confers exceptional depth accuracy and removes the potential of tool-lift at high production rates, allowing logging under conditions that are truly representative of commercial well operation.\u0000 A well that was drilled to a depth in excess of 40,000ft measured depth, with a trajectory designed to maximise the contact between wellbore and reservoir, was completed with a limited entry liner. A total of 37 compartments with lengths between 700ft and 900ft were separated with swell packer assemblies along a horizontal section of 25,000ft. Critical information about the production flow, including toe/heel balance, had been unavailable because of the limitations imposed by the available intervention methods.\u0000 The intervention was designed to fully exploit the physical properties of the carbon composite rod in combination with the most efficient in-well controlled tractoring technology available, and aimed to reach deeper than 40,000ft. Simulations based on previous experience showed that this depth would be achievable with the tractor chosen and further that this could be achieved even with the well flowing at rates of over 5,000BOPD. This meant that deferred production could be minimised along with waiting periods for flow stabilisation.\u0000 The intervention was successfully concluded in a single operation, gathering production data from as deep as 40,600ft. Performance of both rod and tractor aligned with planning simulations with significant margin, indicating further performance enhancements in reach being readily achievable.\u0000 Drilling of such extended reach wells from existing islands will reduce well counts, accelerate development and increase oil recovery by unlocking reserves from the tight rock and areas that are currently unreachable from existing islands and wellhead platforms.\u0000 Technology solutions like carbon composite rod and high-performance tractors enable the operators to acquire production logs & perform well services effectively to maintain the life cycle of extended reach wells inaccessible with conventional solutions.","PeriodicalId":433466,"journal":{"name":"Day 1 Tue, March 21, 2023","volume":"16 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-14","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"134524371","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Mauricio García, J. Olaiya, Baoyan Li, Sebastien Kamgang, D. Patterson, Sushant Dutta
Reliable evaluation of the cement-bonding quality and identification of isolation zones of a cased-hole well are challenging problems, particularly for a plugged and abandoned (P&A) well. Ultrasonic tools have been developed to conduct pitch-catch and/or pulse-echo measurements for cement evaluation at high spatial resolutions. Recently, extended data processing of pitch-catch measurements has been developed to identify third-interface echoes (TIE) from flexural mode waveforms. The derived information of TIEs can be integrated with flexural attenuation rates of casing and acoustic impedances of annulus materials to enhance the accuracy and confidence of evaluations of cement quality and zone isolation. However, there are limitations in conventional pitch-catch measurements. The conventual pitch-catch measurements are longitude measurements. Their vertical resolution is limited by the spacing between transducers. A utilized piezoelectric transducer used by such measurements needs a liquid couplant. The received signals of this kind of sensor are sensitive to the mud density. The heavy mud may cause strong attenuations of intensities of received flexural mode waveforms. Additionally, a piezoelectric sensor is sensitive to the direction of wave propagation. Therefore, a TIE can be missed if two walls of the annulus of a well are not parallel, such as a deviated well. This paper introduces a new compensated pitch-catch measurement method for reliably detecting the eccentricity of the inner pipe and annulus material in a cased-hole environment. The electromagnetic acoustic transducers (EMATs) are utilized to excite and acquire Lamb and shear horizontal waves, respectively, which propagate circumferentially. The operation parameters of this new measurement method are optimized to excite and acquire waves for more reliably extracting TIEs from received waveforms. Compared with piezoelectric sensors, EMAT sensors do not require couplants and are not sensitive to the wave propagation angle, the mud density, and the rugosity of the pipe surface. The vertical resolution of the Lamb wave measurements is controlled by the vertical sampling rate of the tool and the sensor size. This new measurement method has been validated with Lab measurements. The test fixtures with varied annulus spacings were designed, constructed, and cemented. Multiple tests were designed and conducted to verify the modes of Lamb and shear horizontal waves, existences of TIEs with different operation parameters of measurements, and the relations between arrival times of TIE and annulus spacing, as well as filled in materials of annulus. The visibility of TIE for a deviated inner pipe has also been confirmed. The tests results confirmed the optimal operation parameters of this new measurement method. The detected arrival times of TIEs are consistent with their predicted values. This new measurement method has some key technical advantages. The tool measurements do not require a liq
{"title":"Identification of Casing Eccentricity with Third Interface Echo of Waveforms Measured by Electromagnetic Acoustic Transducers","authors":"Mauricio García, J. Olaiya, Baoyan Li, Sebastien Kamgang, D. Patterson, Sushant Dutta","doi":"10.2118/212900-ms","DOIUrl":"https://doi.org/10.2118/212900-ms","url":null,"abstract":"\u0000 Reliable evaluation of the cement-bonding quality and identification of isolation zones of a cased-hole well are challenging problems, particularly for a plugged and abandoned (P&A) well. Ultrasonic tools have been developed to conduct pitch-catch and/or pulse-echo measurements for cement evaluation at high spatial resolutions. Recently, extended data processing of pitch-catch measurements has been developed to identify third-interface echoes (TIE) from flexural mode waveforms. The derived information of TIEs can be integrated with flexural attenuation rates of casing and acoustic impedances of annulus materials to enhance the accuracy and confidence of evaluations of cement quality and zone isolation.\u0000 However, there are limitations in conventional pitch-catch measurements. The conventual pitch-catch measurements are longitude measurements. Their vertical resolution is limited by the spacing between transducers. A utilized piezoelectric transducer used by such measurements needs a liquid couplant. The received signals of this kind of sensor are sensitive to the mud density. The heavy mud may cause strong attenuations of intensities of received flexural mode waveforms. Additionally, a piezoelectric sensor is sensitive to the direction of wave propagation. Therefore, a TIE can be missed if two walls of the annulus of a well are not parallel, such as a deviated well.\u0000 This paper introduces a new compensated pitch-catch measurement method for reliably detecting the eccentricity of the inner pipe and annulus material in a cased-hole environment. The electromagnetic acoustic transducers (EMATs) are utilized to excite and acquire Lamb and shear horizontal waves, respectively, which propagate circumferentially. The operation parameters of this new measurement method are optimized to excite and acquire waves for more reliably extracting TIEs from received waveforms. Compared with piezoelectric sensors, EMAT sensors do not require couplants and are not sensitive to the wave propagation angle, the mud density, and the rugosity of the pipe surface. The vertical resolution of the Lamb wave measurements is controlled by the vertical sampling rate of the tool and the sensor size.\u0000 This new measurement method has been validated with Lab measurements. The test fixtures with varied annulus spacings were designed, constructed, and cemented. Multiple tests were designed and conducted to verify the modes of Lamb and shear horizontal waves, existences of TIEs with different operation parameters of measurements, and the relations between arrival times of TIE and annulus spacing, as well as filled in materials of annulus. The visibility of TIE for a deviated inner pipe has also been confirmed. The tests results confirmed the optimal operation parameters of this new measurement method. The detected arrival times of TIEs are consistent with their predicted values.\u0000 This new measurement method has some key technical advantages. The tool measurements do not require a liq","PeriodicalId":433466,"journal":{"name":"Day 1 Tue, March 21, 2023","volume":"74 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-14","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"133555969","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
M. Ge, Matthew Vick, Mark Reed, Alan Ramnarine, Merrick Kelley, Alex Boheimer
Recent industry trend to increase the production from current offshore assets without significant green field investment require more intervention operations. Riserless light well intervention system is gaining more popularity due to quick turn-around and efficiencies. A typical riserless light well intervention system is composed by coiled tubing downline system, umbilical and wireline system, and well control package. The existing coiled tubing and riserless light well intervention system unfortunately is not designed for open water intervention operations, especially in challenging deepwater environment. For offshore interventions on a floating vessel, the coiled tubing is deployed from a reel through an injector, and is subject to significant dynamic movements due to wave loadings, ocean current and vessel movement. Integration of umbilical, wireline and other pressure control equipment causes additional constraints on the system's already limited operability windows. Additionally, the crowded subsea infrastructure and dropped object risks create extra challenges for safe and efficient operations. This paper presents the key challenges and solutions faced by operators in design and operation of the offshore riserless light well intervention system. The challenges are presented from several perspectives: from the equipment capacity and integrity, system operability limitations, risk awareness, procedure controls, to industry standards. The methods and processes to tackle each challenge are presented. The equipment capacity and weak point are identified and improvement options of various components are evaluated. The equipment improvement opportunities include LARS hoisting capacity assessment, UTA and mudmat tipping over prevention, wireline lazy wave and buoyancy configuration, injector head and guide optimization, subsea jumper and ROV pulling load specification. The operability limitations are increased by engineering analysis optimization and detailed 3D finite element modelling of critical components. Risk awareness and procedure controls are improved by operation guidance and fatigue monitoring mitigations. The novel approaches presented in this paper can be considered for improvement of other riserless light well intervention systems and development of a common industry standard.
{"title":"Enhancing Riserless Light Well Intervention Operability from Operator Perspective","authors":"M. Ge, Matthew Vick, Mark Reed, Alan Ramnarine, Merrick Kelley, Alex Boheimer","doi":"10.2118/212915-ms","DOIUrl":"https://doi.org/10.2118/212915-ms","url":null,"abstract":"\u0000 Recent industry trend to increase the production from current offshore assets without significant green field investment require more intervention operations. Riserless light well intervention system is gaining more popularity due to quick turn-around and efficiencies. A typical riserless light well intervention system is composed by coiled tubing downline system, umbilical and wireline system, and well control package. The existing coiled tubing and riserless light well intervention system unfortunately is not designed for open water intervention operations, especially in challenging deepwater environment.\u0000 For offshore interventions on a floating vessel, the coiled tubing is deployed from a reel through an injector, and is subject to significant dynamic movements due to wave loadings, ocean current and vessel movement. Integration of umbilical, wireline and other pressure control equipment causes additional constraints on the system's already limited operability windows. Additionally, the crowded subsea infrastructure and dropped object risks create extra challenges for safe and efficient operations.\u0000 This paper presents the key challenges and solutions faced by operators in design and operation of the offshore riserless light well intervention system. The challenges are presented from several perspectives: from the equipment capacity and integrity, system operability limitations, risk awareness, procedure controls, to industry standards. The methods and processes to tackle each challenge are presented.\u0000 The equipment capacity and weak point are identified and improvement options of various components are evaluated. The equipment improvement opportunities include LARS hoisting capacity assessment, UTA and mudmat tipping over prevention, wireline lazy wave and buoyancy configuration, injector head and guide optimization, subsea jumper and ROV pulling load specification. The operability limitations are increased by engineering analysis optimization and detailed 3D finite element modelling of critical components. Risk awareness and procedure controls are improved by operation guidance and fatigue monitoring mitigations. The novel approaches presented in this paper can be considered for improvement of other riserless light well intervention systems and development of a common industry standard.","PeriodicalId":433466,"journal":{"name":"Day 1 Tue, March 21, 2023","volume":"20 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-14","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"115593680","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Use of metal-on-metal lubricants is a common way to enhance coiled tubing (CT) accessibility in extended reach (ER) wells. However, there is less data available on the effect of lubricants in open-hole applications. Historically, there is only a laboratory study (Sharma and Silviu 2020) that evaluated the effect of lubricants in an open-hole environment. This paper will discuss methodology and results from a 2-in CT field trial where a special CT metal-on-metal lubricant was utilized inside an open-hole completion to enhance accessibility to perform acid stimulation. The wells have measured depth over 17,000-ft with about 7,000-ft of 6-in open-hole lateral, requiring CT acid stimulation. The open-hole formation type is carbonate with permeability values ranging up to 10 mD. The operator requires CT to reach maximum possible depth, providing maximum coverage for acid stimulation. Proprietary CT software is used to model CT accessibility with sensitivity analysis performed with possible coefficient of frictions (CoF) expected from the laboratory research mentioned earlier. The methodology of applying the special CT lubricant is based on filling the entire well with the lubricant solution to maximize CT accessibility. These field trials were executed in October and November 2022. The plan was to run CT to the maximum possible depth in the absence of lubricant. Upon attaining friction lock, base CoF will be analyzed, and CT will be picked up to a certain depth. Special CT lubricant then will be applied at 2% concentration mixed in fresh water by pumping across the CT tubing annulus and via CT in the open-hole while running inside the hole. The special CT lubricant used in this case study was field proven to provide up 40-60% reduction in metal-on-metal CoF based on previous applications in cased completions. The open-hole effectiveness was predicted and modelled based on previous laboratory studies conducted (Sharma and Silviu 2020), which was observed to be in the range of 20 – 40% reduction in CoF for limestone samples. The actual CoF analyzed on one of the field trials was 17%. Being a first-time application of special CT lubricant in open-hole environment, the methodology and results from this field trial will enable application in open-hole wells with similar formations, globally. With more applications of metal-on-non-metal lubricants, it will provide better understanding to the industry on their behaviors downhole.
{"title":"Field Trial to Enhance Open-Hole Coiled Tubing Accessibility with the Use of a Special Coiled Tubing Lubricant","authors":"S. Chishti, Bathmanaaban Gopalan, S. Craig","doi":"10.2118/212903-ms","DOIUrl":"https://doi.org/10.2118/212903-ms","url":null,"abstract":"\u0000 Use of metal-on-metal lubricants is a common way to enhance coiled tubing (CT) accessibility in extended reach (ER) wells. However, there is less data available on the effect of lubricants in open-hole applications. Historically, there is only a laboratory study (Sharma and Silviu 2020) that evaluated the effect of lubricants in an open-hole environment. This paper will discuss methodology and results from a 2-in CT field trial where a special CT metal-on-metal lubricant was utilized inside an open-hole completion to enhance accessibility to perform acid stimulation.\u0000 The wells have measured depth over 17,000-ft with about 7,000-ft of 6-in open-hole lateral, requiring CT acid stimulation. The open-hole formation type is carbonate with permeability values ranging up to 10 mD. The operator requires CT to reach maximum possible depth, providing maximum coverage for acid stimulation. Proprietary CT software is used to model CT accessibility with sensitivity analysis performed with possible coefficient of frictions (CoF) expected from the laboratory research mentioned earlier. The methodology of applying the special CT lubricant is based on filling the entire well with the lubricant solution to maximize CT accessibility.\u0000 These field trials were executed in October and November 2022. The plan was to run CT to the maximum possible depth in the absence of lubricant. Upon attaining friction lock, base CoF will be analyzed, and CT will be picked up to a certain depth. Special CT lubricant then will be applied at 2% concentration mixed in fresh water by pumping across the CT tubing annulus and via CT in the open-hole while running inside the hole. The special CT lubricant used in this case study was field proven to provide up 40-60% reduction in metal-on-metal CoF based on previous applications in cased completions. The open-hole effectiveness was predicted and modelled based on previous laboratory studies conducted (Sharma and Silviu 2020), which was observed to be in the range of 20 – 40% reduction in CoF for limestone samples. The actual CoF analyzed on one of the field trials was 17%.\u0000 Being a first-time application of special CT lubricant in open-hole environment, the methodology and results from this field trial will enable application in open-hole wells with similar formations, globally. With more applications of metal-on-non-metal lubricants, it will provide better understanding to the industry on their behaviors downhole.","PeriodicalId":433466,"journal":{"name":"Day 1 Tue, March 21, 2023","volume":"56 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-14","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116824794","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Rao Shafin Ali Khan, N. Molero, Shahnawaaz Alam, Mohammad Basim Mishael, Maged Basha, Arslan Zia, Sholpan Zhylkaidarova, Mohamed Osama Abd El-Meguid, Abdulrahman Hasan Al Ali, A. Saleh, S. Almazrouei, Ayman El Shahat, Ali Sulaiman Bin Sumaida, Ahmed Abdulla Al Mutawa, Fawad Zain Yousfi, Nama Ali Almteiri, M. Baslaib, A. Mantilla, A. Ladmia
United Arab Emirates is seeking to become self-sufficient in gas supply by 2030. This has led the country to initiate several exploratory and appraisal projects to achieve this goal. This study covers one such pilot project targeting production from tight gas reservoirs in three wells through coiled tubing (CT) underbalanced drilling (UBD) project in ADNOC Onshore. CT pressure control equipment was rigged up on top of production trees with wells already completed and cemented. A CT tower was used to accommodate the drilling bottomhole assembly (BHA) and eliminate risks related to its deployment. CT strings were designed to reach target intervals with sufficient weight on bit (WOB), suitable for sour environment, and able to withstand high pumping rates with mild circulating pressures. To address the hazards of H2S handling at surface, a custom-fit closed-loop system was deployed. The recovered water was treated on surface and reused for drilling to decrease the water consumption throughout the operations. The plan was to drill three 3/4-in. horizontal laterals in all candidate wells. Each well was completed with a combination of a 4 1/2-in. and a 5 1/2-in. tubing and a 7-in. liner. Five laterals were drilled across the three candidate wells targeting carbonate reservoirs with each lateral having an average length of ∼4,000 ft. The achieved rates of penetration varied significantly from 15 ft/min to 30 ft/min while drilling through the various formations. Over the course of the pilot project, several challenges had to be addressed, such as material accretion on the CT string during wiper trips, treatment of return fluids having high H2S content and rock cuttings and ensuring integrity of the CT pipe while operating in severe downhole environments. Solutions and lessons learnt from each well were implemented subsequently in the campaign, such as the use of increased concentrations of H2S inhibitor to coat the CT string, use of nitrified fluids based on changing well parameters to maintain underbalance, thorough pipe management through real-time CT inspection, and adding a fixed quantity of fresh water to the drilling system every day to avoid chemical reactions between the drilling fluid additives and hydrocarbons. The wells completed with this method exceeded production expectations by 35 to 50% across the project, while reconfirming the value of the technology. The use of CT for UBD is still considered a challenging intervention worldwide. Such cases in high H2S environments are rare. This study outlines best practices for a CT UBD and a setup that can be replicated in other locations to implement this methodology with high H2S and when rig sourcing is a concern.
{"title":"Underbalanced Coiled Tubing Drilling: Delivering Well Production Safely in High H2S and Tight Gas Reservoirs, UAE","authors":"Rao Shafin Ali Khan, N. Molero, Shahnawaaz Alam, Mohammad Basim Mishael, Maged Basha, Arslan Zia, Sholpan Zhylkaidarova, Mohamed Osama Abd El-Meguid, Abdulrahman Hasan Al Ali, A. Saleh, S. Almazrouei, Ayman El Shahat, Ali Sulaiman Bin Sumaida, Ahmed Abdulla Al Mutawa, Fawad Zain Yousfi, Nama Ali Almteiri, M. Baslaib, A. Mantilla, A. Ladmia","doi":"10.2118/212890-ms","DOIUrl":"https://doi.org/10.2118/212890-ms","url":null,"abstract":"\u0000 United Arab Emirates is seeking to become self-sufficient in gas supply by 2030. This has led the country to initiate several exploratory and appraisal projects to achieve this goal. This study covers one such pilot project targeting production from tight gas reservoirs in three wells through coiled tubing (CT) underbalanced drilling (UBD) project in ADNOC Onshore.\u0000 CT pressure control equipment was rigged up on top of production trees with wells already completed and cemented. A CT tower was used to accommodate the drilling bottomhole assembly (BHA) and eliminate risks related to its deployment. CT strings were designed to reach target intervals with sufficient weight on bit (WOB), suitable for sour environment, and able to withstand high pumping rates with mild circulating pressures. To address the hazards of H2S handling at surface, a custom-fit closed-loop system was deployed. The recovered water was treated on surface and reused for drilling to decrease the water consumption throughout the operations.\u0000 The plan was to drill three 3/4-in. horizontal laterals in all candidate wells. Each well was completed with a combination of a 4 1/2-in. and a 5 1/2-in. tubing and a 7-in. liner. Five laterals were drilled across the three candidate wells targeting carbonate reservoirs with each lateral having an average length of ∼4,000 ft. The achieved rates of penetration varied significantly from 15 ft/min to 30 ft/min while drilling through the various formations. Over the course of the pilot project, several challenges had to be addressed, such as material accretion on the CT string during wiper trips, treatment of return fluids having high H2S content and rock cuttings and ensuring integrity of the CT pipe while operating in severe downhole environments. Solutions and lessons learnt from each well were implemented subsequently in the campaign, such as the use of increased concentrations of H2S inhibitor to coat the CT string, use of nitrified fluids based on changing well parameters to maintain underbalance, thorough pipe management through real-time CT inspection, and adding a fixed quantity of fresh water to the drilling system every day to avoid chemical reactions between the drilling fluid additives and hydrocarbons. The wells completed with this method exceeded production expectations by 35 to 50% across the project, while reconfirming the value of the technology.\u0000 The use of CT for UBD is still considered a challenging intervention worldwide. Such cases in high H2S environments are rare. This study outlines best practices for a CT UBD and a setup that can be replicated in other locations to implement this methodology with high H2S and when rig sourcing is a concern.","PeriodicalId":433466,"journal":{"name":"Day 1 Tue, March 21, 2023","volume":"11 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-14","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"114909210","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
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