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Collaborating Authors
Results
Operational Improvements Using a Coiled Tubing Telemetry System for a Complex Milling Operation in Shut-in Conditions
Kubeisinova, A.. (KPO) | Tankiyev, T.. (KPO) | Izbassov, A.. (KPO) | McGachy, D.. (KPO) | Viti, M.. (KPO) | Pitoni, E.. (KPO) | Correa, P.. (Baker Hughes, a GE Company) | Parra, D.. (Baker Hughes, a GE Company) | Craig, S.. (Baker Hughes, a GE Company) | Livescu, S.. (Baker Hughes, a GE Company) | Yeginbayev, A.. (Baker Hughes, a GE Company) | Nadirov, Z.. (Baker Hughes, a GE Company)
Abstract A new horizontal well in Asia was not capable of unassisted flow due to low gas production rates and a wellhead pressure below that required to enter the production gathering system. Two zones were identified at the heel that could increase the gas/oil ratio (GOR). Because these two zones had deviations greater than 80 degrees, coiled tubing (CT) was selected for the perforation and stimulation intervention. In addition, mechanical isolation was required to ensure the stimulation fluids entered only the new zones. Accurate depth control was required for three runs: setting two composite bridge plugs (CBPs); deploying CT-conveyed perforating (TCP) guns for opening two intervals; and milling out the two CBPs without taking returns to surface. All these runs were performed with a 2.875-in. tube wire-enabled CT telemetry (CTT) system. For the first time, a tension, compression and torque (TCT) subassembly was used to improve the milling operation. The CTT system consists of a customized bottomhole assembly (BHA) that instantaneously transmits internal (i.e., inside the BHA) and external (i.e., outside the BHA) pressure and temperature, and casing collar locator (CCL) data to surface through a non-intrusive tube wire installed inside the CT. Monitoring the BHA force and torque data in real time helped improve the motor and mill performance and life because the weight on bit (WOB) could be adjusted to the recommended values. For instance, based on the optimum working ranges for the motor used, the operator decided how and when to modify the working variables to achieve a reliable and efficient milling process. The CTT system alone helped set the first CBP at 5363 m measured depth (MD), set the second CBP at 5281 m MD, and perforate the intervals between 5297 and 5306 m MD and between 5152 and 5164 m MD. In addition, the CTT system with the TCT subassembly was used to mill the two CBPs in shut-in conditions, without any stalls. This created a continuous milling operation, reducing the job time and the working fluid volume compared to similar milling jobs using CTT system alone. Comparing this CBP milling job performance with a previous operation in another well with similar conditions (depth, deviation, etc.) using the CTT system alone reduced the milling time for one CBP by 22%. Although the overall job performance exceeded the operator's expectations, the working parameters used during the CTT system with the TCT sub-assembly job were not constant, leaving a few areas of improvement for the upcoming milling operations. For instance, the constant differential pressure and WOB were not used on every milling pass down. The novelty of using the CTT system and TCT subassembly consists of real-time monitoring of BHA data for positioning two CBPs and opening new intervals exactly at the required depths. In addition, this approach enables removal of two CBPs by adjusting the milling parameters to achieve the optimum working parameters for the motor and mill, providing direct and positive financial impact for the operator.
- Asia (1.00)
- North America > United States > Texas (0.69)
Abstract Cement plugs are a widely used well intervention method to achieve zonal isolation and well plug and abandonment. The current practice of cementing using wireline was reviewed on a system level to identify the primary challenges. Existing cement mix properties, such as compressive strength and wait-on-cement (WOC) time, were characterized using standard API RP 10B-2 (2013) tests. The sensitivity of these mixes to various wellbore temperature and pressure conditions was also studied. Based on the understanding of the current practice, modifications of the compositions, packaging, and mixing procedures in the field were proposed and tested accordingly. Based on the experimental results, the properties of the current cement mixes showed high sensitivity to temperature variations as small as 10°F. To achieve a cement plug as expected, accurate knowledge of the well temperature profile and precise selection of the best additives for such small temperature intervals are necessary. If crossflow occurs, then setting a plug itself can change the temperature profile. This makes cement plug operations even more challenging during actual field practice. The cement mixes were modified and tailored to reduce their sensitivity to temperature without affecting the dump time and strength development. This paper discusses the challenges associated with wireline-run cementing operations and presents a simple and streamlined process developed to help reduce operational time and minimize costs. The study also discusses cement mixes customized for dump bailer operations.
Abstract Instrumentation and surface control improve the success rates and efficiency of wireline rotary brushing and honing. Data based operational planning and real-time data feedback allow for efficient operations with measurable outcomes. This paper compares two types of instrumented, wireline-powered rotary cleaning assemblies by assessing their performance, cleaning efficiency, operational factors, and real-time logging outputs. Basic rotary brushing physics along with characterization curves of the systems explain the relationship between operational factors including rotational speed, torque, and downhole power requirements. Models of the operational factors were created so that preoperational planning and real-time data interpretation can be used to verify intervention objectives.
Abstract This paper presents a case history where the entire lateral of a producing well was restimulated in a single trip using a novel cost-effective intervention tool designed to provide discrete stage isolation. Lessons learned and job details are discussed and compared with other restimulation methods used in the area. The new method is based on a novel straddle packer system that uses two mechanically-activated sealing elements—as opposed to conventional sealing cups—to overcome wear and bottomhole pressure limitations found in traditional straddle systems. The novel stage isolation system enables higher flow rates and pressure differentials as well as a larger number of stages, therefore reducing the amount of trips in the well required to complete typical refracturing operations. A comparison will be made to conventional refracturing methods based on intervention tools. As a bonus, pressure data gathered during the treatment indicating limited coverage of the primary fracturing job will be discussed. The case study provides the framework to describe how the novel technology enables multiple treatments in a single trip in the horizontal well, therefore reducing the operational time, resources, and cost required to complete a restimulation job. The paper will show how the use of the novel technology reduced operational time by 30% compared to other methods, and enabled the operator to treat a horizontal well with full mechanical isolation in a manner not previously available. In addition, the paper will discuss pressure data gathered during the deployment that suggests limited cluster efficiency on the primary fracturing operation. The results of the paper are relevant because they provide a new cost-effective alternative to conventional restimulation systems that was not available in the past due to inherent technology limitations of existing straddle packer systems. This is important because: (1) the technology described in the paper overcomes these limitations for both vertical and horizontal wells, (2) more refracturing operations are executed by blindly pumping treatments from surface into a full lateral with open perforations without an effective way to mechanically isolate target zones, and (3) the technology may shed additional light on the discussion of cluster efficiency during primary stimulation operations.
- North America > United States > Texas (0.83)
- North America > United States > New Mexico (0.51)
- North America > United States > Texas > Permian Basin > Yeso Formation (0.99)
- North America > United States > Texas > Permian Basin > Yates Formation (0.99)
- North America > United States > Texas > Permian Basin > Wolfcamp Formation (0.99)
- (24 more...)
- Well Completion > Hydraulic Fracturing > Re-fracturing (1.00)
- Well Completion > Completion Installation and Operations > Perforating (1.00)
- Management > Professionalism, Training, and Education > Communities of practice (1.00)
- Data Science & Engineering Analytics > Information Management and Systems > Knowledge management (1.00)
Abstract One of the biggest sources of dry gas in the world is located in the Middle East. Every project in this field faces challenges that require good-quality downhole data to be properly addressed. In the present case, the risks involved when milling inside a 7-in. monobore completion with 2 3/8-in. coiled tubing (CT) in gas conditions motivated the use of a state-of-the-art bottomhole assembly capable of providing real-time downhole parameters to operate the mill both safely and efficiently. The project, which included an extensive integration between the CT and downhole tools providers, consisted of various innovative stages. First, a stimulation vessel was used to deliver enough pumping capacity to inject the fiber optics carrier into the CT pipe located on the rig. Then, a customized surface acquisition system was implemented to comply with strict zoning requirements, and protocols and hardware were designed for communication between the software of all parties to transmit downhole and surface data in real time. Finally, a thorough analysis was conducted to identify the safest method to deploy and run the milling tools to achieve the job objective. This successful milling operation in 7-in. monobore completion and gas conditions was the result of several achievements made throughout the project. The real-time telemetry system served rugged downhole tools, which were being used under these conditions for the first time. They provided downhole torque, pressure (both inside and outside of the milling tool), depth control variables, and weight on bit to the CT control cabin, where the CT operator and milling tool specialist effectively interpreted the data and took actions to mill 100 ft of cement and a drillable plug in three runs. The critical operation to inject the fiber optic carrier in the 2 3/8-in. CT pipe required incorporating extra measurement equipment such as flowmeters and pressure gauges in the system to closely check pumping parameters, which will now be utilized as a standard for other such interventions worldwide. Finally, the design of the communication interface between the software of the different companies proved to be effective at compiling all the critical parameters and became a benchmark for future operations. Even though well conditions changed during the operation, the job was executed safely based on a detailed decision tree that incorporated several contingencies. Each action was reviewed by all parties based mainly on the downhole data recorded, which allowed getting the best out of the milling bottomhole assembly and the expertise incorporated in the project. This work shares a vast amount of information collected during the design and execution of the project. The significant effort performed by all the parties to integrate their equipment and technology are detailed within the context of the job's objectives and can be used as a reference by other locations. Contingency plans are also detailed, as well as safety measures and lessons learned.
- Asia > Middle East > Saudi Arabia (0.28)
- North America > United States > Texas (0.28)
- Well Completion > Completion Installation and Operations > Coiled tubing operations (1.00)
- Production and Well Operations > Well Intervention (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring (1.00)
- Data Science & Engineering Analytics > Information Management and Systems (1.00)
Abstract The use of conventional downhole batteries, which are intended for low voltage/current, faces hurdles when it comes to operating tools designed for surface power provided through a cable. The high power consumed by some of these tools requires careful characterization of parameters such as current, transients, and battery capacity at different loads and temperatures. The battery power tool developed for high-power tools uses three battery packs, here used in series, to boost input voltage, with a provision to use three additional packs in parallel for additional current. Battery characterization efforts at currents higher than 1 A were performed at different temperatures (75°C, 100°C, and 150°C) to explore the behavior of lithium battery chemistry, with a total of 48 battery packs tested. The electronics design to boost battery voltage up to 200 V to support a pulsed neutron tool is also presented. The result of this engineering effort is a system that can provide more than 20 Ah of power and enables more than 10 hours of continuous operation of pulsed neutron tools. It also allows more than 100 hours of operation of conventional production logging tools. A tool planner software is provided for the field users to estimate the battery operation time for a specific job. Those benefits are illustrated by the field deployment results of this solution since 2014, with examples of successful operations in the Kingdom of Saudi Arabia, the Congo, and Gabon.
- Africa > Gabon (0.25)
- Asia > Middle East > Saudi Arabia (0.25)
- Energy > Oil & Gas > Upstream (1.00)
- Energy > Energy Storage (1.00)
- Electrical Industrial Apparatus (1.00)
- Africa > Gabon (0.89)
- Africa > Angola > South Atlantic Ocean > Congo Basin (0.89)
- Well Completion (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Open hole/cased hole log analysis (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring > Production logging (1.00)
- Data Science & Engineering Analytics > Information Management and Systems (1.00)
Abstract During the last three decades a coiled tubing (CT) modeling software package has been continuously developed to assist in the planning and executing of global CT operations. The first models were steady-state. In the past decade these models have been extended to consider transient effects of operations as they are executed. These models will also be used in the not-so-distant future to automate CT operations. In this paper, a review of all these models is presented for the first time. The development of a computer program was initiated in the early 1980s to help understand the downhole flow and pressure conditions during CT operations. Utilizing multi-phase rheological and frictional correlations obtained from laboratory flow loop testing, the CT flow model was extensively validated against global field data. Later, CT force and stress analysis models, considering such effects as the specific well geometry, mechanical friction, CT size, shape and material strength, were developed to predict lateral reach and assist in preventing downhole CT failures. While the most common and simplest approach within the industry is still to use steady-state models, in practice, the downhole conditions during CT operations, such as well cleaning, well unloading, well control, stimulation, cementing, underbalanced drilling with nitrified fluid, etc., are transient. Consequently, the steady-state models have been extended to account for downhole transient effects at the pre-planning and execution stages of CT operations. In addition, with the advent of the state-of-the-art CT telemetry systems, it is possible to acquire the downhole data in real time and use the transient CT software model to automate and optimize CT operations, increasing their safety and efficiency. A review is presented for the first time about the steady-state and transient models included in the CT software model, with details about each model and how they performed during 30 years of operations. Results and discussions regarding the extensive validation of the software against laboratory and field data are also presented. Several field cases from around the world help illustrate the transient nature of CT operations and the benefits of using the transient simulation in the pre-planning and execution stages of these operations. The paper presents the results from 30 years of global experience with the CT modeling software program. The mathematical models, validation against laboratory and field data, verification against other models available in literature, and case histories are described. The current trends within the industry are leading to a shortage of experienced CT field engineers, so the use of CT software models to increase the efficiency, compliance and safety of CT operations has never been as important as now.
- Europe (1.00)
- North America > United States > Texas > Montgomery County (0.28)
- Information Technology > Software (1.00)
- Information Technology > Modeling & Simulation (1.00)
- Information Technology > Architecture > Real Time Systems (0.69)
Abstract In North America, refracturing has been found to be effective in many instances for increasing the longevity of the well production and helping to drill and complete offset wells. Several instances suggest that refracturing by bull-heading is relatively ineffective because fluids and proppants are lost in the pre-existing hydraulic fractures. Refracturing through coiled tubing (CT) provides a large benefit in giving ability to pinpoint the location of the refracturing treatment by creating new perforations using abrasive jetting and using diversion pills for isolating high-permeability clusters. This paper helps elucidate the benefits and production gain when using CT for refracturing jobs. A case study from the Eagle Ford shale illustrates the impact of CT refracturing applications. When CT was hydraulic fracturing was applied in the first generation of wells with 18 stages, 36% extra production was observed in the first year as compared to the bullheading technique. Simulations based on integrated reservoir and geomechanical earth models, complex hydraulic fracture models, diversion simulation, numerical production simulation and finite element computations enable characterizing the productivity from the CT refrac operations. A comparison is made between the bullheading technique and CT based refracturing jobs. The impact of refracturing using CT on the offset child wells to be drilled and completed is also studied. The study demonstrates that it is critical to place the perforation locations in areas of undepleted reservoir for successful refracturing. Reservoir simulation results in combination with measurements of fluid flow profile in the wellbore can be used to place new perforations in the right sections. Using the diversion pill was found to be greatly effective in improving the fracturing fluid diversion and stimulating the undrained reservoir. With the refracturing using CT, the child wells show improvement in productivity along with the parent well. Overall, the parent and child well combination shows 23% increase in production after one year of refracturing when compared to no refracturing in the parent wellbore. The new approach is verified through the application of simulation and modeling to prove the benefit of CT refracturing operations in unconventional reservoirs. By adopting the key learnings and approach followed in this paper, operators can maximize their chances to improve productivity and compare various refracturing scenarios.
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Petroleum Play Type > Unconventional Play > Shale Play (0.48)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.35)
- North America > United States > West Virginia > Appalachian Basin > Marcellus Shale Formation (0.99)
- North America > United States > Virginia > Appalachian Basin > Marcellus Shale Formation (0.99)
- North America > United States > Texas > West Gulf Coast Tertiary Basin > Eagle Ford Shale Formation (0.99)
- (7 more...)
Electric Line Deployed Orientated Suction Cleanout Device Enables Gas Lift Valve Retrieval from Debris Blocked Side Pocket Mandrel in a Highly Deviated Well
Murchie, Stuart (ALTUS Intervention) | Gjertsen, John (ALTUS Intervention) | Grødem, Magne (ALTUS Intervention) | Sætrevik, Martin Severin (ALTUS Intervention) | Osaland, Espen (ALTUS Intervention) | Sørensen, Peter Lykke (ALTUS Intervention) | Hansen, Steen Korsgaard (INEOS DeNoS.)
Abstract The client had a leaking gas lift valve (GLV), which needed to be replaced to restore the integrity of the well. The side pocket mandrel (SPM), was located at a high angle part of the well, positioned on the low side and sand debris had accumulated in and around the GLV, impairing its retrieval. Tests carried out on surface to attempt to latch a GLV through the sand proved ineffective, even with jarring. To further optimise production, SPMs are being installed at increasing well depths, enabling deeper gas injection into the tubing. Placing SPMs into the high angle section of deviated wells inherently increases the risk of them retaining debris, as was the case in this well. A novel solution, to remove the accumulated sand debris from the SPM was proposed, utilising an orientation sub, run in conjunction with an electric line deployed tractor-suction tool configuration, incorporating a bespoke side facing inlet nozzle. Tests on the designed solution were conducted in the engineering facility, recreating the deviation, orientation and debris expected and evaluating the nozzle alignment and cleanout capability for the expected debris type. These tests proved to be highly successful, giving the customer the confidence to perform the job. The deviation also necessitated electric line tractor deployment of a modified retrieval device. Following a drift and plug setting run, the well tractor and suction tool assembly was deployed and two litres of sand was collected from within the SPM. The subsequent run to pull the faulty GLV was successful, as was the deployment of a replacement GLV. The operation proved this to be an excellent and highly effective example of a rapidly designed and tested, bespoke, electric line deployed SPM cleanout solution.
- Well Completion (1.00)
- Production and Well Operations > Artificial Lift Systems > Gas lift (1.00)
Abstract A wireline tractor has been developed with an integrated individual arm-closing mechanism that enables losing traction in only one arm while all the others are delivering the traction necessary to overcome the increased force in navigating an obstacle. Wireline tractors convey logging tools, perforating guns, and mechanical services in highly deviated and horizontal wells. In many cases, they are an efficient alternative to coiled tubing because of their small footprint, quick deployment, minimal flow disruption, and fast tractoring speed. However, tractors cannot easily negotiate obstacles such as restrictions, completion equipment, pipe damage, and debris accumulation. This problem is tied to the traction principle. When the tractor encounters an obstacle, higher push force is required, which means higher pressure is needed on the arms to increase the grip. At the same time, one arm must close to navigate the obstacle, which requires lower arm pressure. The solution has been to operate two entire tractors in tandem and close one tractor at a time through the restriction. This method necessitates to run an excessive number of assets and increases the toolstring length. To solve this problem, a wireline tractor has been developed that uses an individual arm-closing mechanism. This unique feature enables losing the traction of only one arm while the other arms are delivering the traction to overcome the increased force. This mechanism is built in the tool and is available at any time without any specific tool preparation, planning, or module addition, which eliminates undesirable trips in and out of the wells to reconfigure the toolstring in case of an unexpected obstacle. This innovation has been successfully qualified in many tractor operations. Two cases in the Gulf of Mexico offshore and in North America land will be presented in which this feature was instrumental to reduce the toolstring length and asset overdeployment in overcoming expected and unexpected completion restrictions. In the first operation, this solution enabled to navigate several side pocket mandrels, which are well-known challenges for tractors due to their complex geometries. In the second case, it saved a deemed inevitable trip to reconfigure the tractor on surface when the tractor encountered an unexpected completion restriction. The breakthrough design of the arm-closing mechanism significantly increases overall tractor ability to successfully reach the job objective while reducing nonproductive time, resulting in more efficient operations and reduced costs.