Effective Zonal Isolation Straddle Deployment in a Slim Deviated Well using Electric Line Tractor / Stroker Combination

2021 ◽  
Author(s):  
Muhammad Nabil Ghazali ◽  
Kasim Selamat ◽  
Stuart William Murchie ◽  
Rosano F. Sosrohadisewoyo ◽  
Matthieu Billaud
Keyword(s):  
System Integration ◽  
Lessons Learned ◽  
Sand Production ◽  
Well Production ◽  
Well Completion ◽  
Electric Line ◽  
Optimal Capacity ◽  
Integration Test ◽  
Pulling Forces ◽  
Well Trajectory

Abstract Due to sand production coming from the upper zone of a multizone monobore gas well completion, the well production had to be choked back to a flow rate below the well's maximum sand free rate (MSFR). This resulted in suboptimal production. A straddle packer assembly was installed across this upper zone, which isolated the sand production and, therefore, enabled the choke to be removed and the well production to be increased to its true, optimal capacity. Several previous attempts to deploy and install the straddle components at their required depth using the prescribed slickline deployment method proved unsuccessful, because of hold ups that occurred while running in hole—due to a well trajectory of 72 degrees deviation and 4.579 deg/100 ft dog leg severity, coupled with the small tubing inside diameter (ID) associated with the slim 3 ½ in. completion. Furthermore, it was found that insufficient forces were available via slickline deployment to execute the related stabbing, setting and release actions required during in-well straddle component installation, because of the limited jar down weight available and safe working load limits on the slickline at the setting depth. As a result, a slim 2 ⅛ in. electric line tractor was utilised, in combination with a 2 ½ in. electrohydraulic linear actuator (stroker). The tractor conveyed the various straddle packer and spacer elements (straddle tubes) to depth and the stroker installed these components in the well to confirm their engagement and to ensure their controlled and confirmed release. Being bi-directional by design, the stroker provided both the upward and downward forces required for component installation—stabbing, setting, and pin shearing to release. The stroker was also available in the toolstring in case of any inadvertent tool sticking encountered while running in hole due to the well trajectory and produced sand debris. A system integration test (SIT) was meticulously planned and executed by the relevant operator and service company representatives before the operation. It was used to confirm the stroker's capability to stab and set the straddle tube into the lower packer and to shear the running tool used to install the straddle tubes and upper packer. This included the installation of straddle tubes into the lower packer section, done in a horizontal configuration and completed using higher setting and pulling forces than those expected during the actual job to ensure more than adequate forces would be available. The operation was executed successfully following the newly defined program, applying the lessons learned from the SIT. A total of four runs were carried out using the combined tractor/stroker deployment string configuration without any in-well deployment issues—the straddle component installation completed with 100% operational efficiency. Following this, the well was put back onto production and the production rate increased from approximately 1 million standard cubic feet per day (MMscf/D) to 3 MMscf/D, with no sand production observed at surface. Having not been done before, this methodology proved to be a successful option for the operator for straddle packer assembly deployment in deviated slim wells.

Increasing Operational Efficiency in Extended Reach, Offshore Wells – A Case Story from Middle East

2016 ◽  
Author(s):  
Anthony MacLeod
Keyword(s):  
System Integration ◽  
Cost Effective ◽  
Lessons Learned ◽  
Operating Efficiency ◽  
Coiled Tubing ◽  
Electric Line ◽  
Release Device ◽  
Integration Test ◽  
Closed Position ◽  
Shifting Profile

ABSTRACT Objective A case story from ME will be presented covering an extreme extended reach, offshore well. Any increase to operating efficiency can save time and increase production. In this case story two SSD's were opened in a single run on e-line, an outstanding achievement due to the ID restrictions and extended reach of the well. The paper will discuss the planning, the operation, the achievements and the lessons learned. Methods, Procedures, Process This well was recently worked over, retrieval and new installation of upper and lower completion. Due to the well going on total losses during the workover, a closed system was deployed to enable the operator to set the hydraulic packers. The packer is utilized for isolation between two zones, with each zone having two SSD's in which one SSD per zone was required to be opened to allow access to the formation. From day one of planning the primary solution for this intervention was an electric over hydraulic toolstring made up of five tools, a 218 electric release device, 218 CCL for correlation, a 218 tractor for conveyance, a 218 stroker for the mechanical manipulation and a 218 key to address the shifting profile in the SSD (toolstring). A slimhole toolstring was required due to the packer ID of 2.81" The operator was using the service provider for other interventions on this workover campaign and decided to challenge them with opening two SSD's in one run while not shifting the adjacent SSD's. The challenging underlying economics of the industry today has created a powerful driver for operators to find more efficient, cost effective and safer intervention methodologies. The operation covered in this case provided just such improvements to the client: by utilizing electric line intervention tools the operator negated the requirement for a large footprint coiled tubing intervention. Results, Observations, Conclusions A System Integration Test (SIT) was completed onshore prior to mobilization, where multiple shifts were successfully executed on a 90° deviated pipe using a single set of shifting key pads. Test results were then repeated offshore, completing two interventions in a single run. The SSD's were successfully opened at ~12,000 ft MDRT and ~8,000 ft MDRT, respectively while leaving the two adjacent SSD's in the closed position. Results, client objective was 100% achieved using only electric line, enabling the client to move forward with similar well designs having the confidence that a safe, reliable electric line solution is locally available. Additional results include reduced HSE risks as the e-line approach eliminated the use of a heavier CTU. Further contributing to the HSE benefits on this operation, only 6 persons were needed on site and no heavy lifts were required. The paper will also cover some lessons learned as debris in the profile and tubing caused some challenges. Novel/Additive Information This operation shows how the industry is constantly trying to improve on existing methods in order to be more efficient, safe and cost effective.

Malaysia's First Successful Implementation of Sand Consolidation Technology as a Primary Sand Control Method Executed during the Drilling Phase: Success Story and Lessons Learned

2021 ◽  
Author(s):  
Nadiah Kamaruddin ◽  
Nurfuzaini A Karim ◽  
M Ariff Naufal Hasmin ◽  
Sunanda Magna Bela ◽  
Latief Riyanto ◽  
...  
Keyword(s):  
Control Method ◽  
Movement Control ◽  
Lessons Learned ◽  
Successful Implementation ◽  
Success Story ◽  
Control Solution ◽  
Consolidation Process ◽  
Execution Plan ◽  
Well Completion ◽  
Sand Control

Abstract Field A is a mature hydrocarbon-producing field located in eastern Malaysia that began producing in 1968. Comprised of multistacked reservoirs at heights ranging from 4,000 to 8,000 ft, they are predominantly unconsolidated, requiring sand exclusion from the start. Most wells in this field were completed using internal gravel packing (IGP) of the main reservoir, and particularly in shallower reservoirs. With these shallower reservoirs continuously targeted as good potential candidates, identifying a sustainable sand control solution is essential. Conventional sand control methods, namely IGP, are normally a primary choice for completion; however, this method can be costly, which requires justification during challenging economic times. To combat these challenges, a sand consolidation system using resin was selected as a primary completion method, opposed to a conventional IGP system. Chemical sand consolidation treatments provide in situ sand influx control by treating the incompetent formation around the wellbore itself. The initial plan was to perform sand consolidation followed by a screenless fracturing treatment; however, upon drilling the targeted zone and observing its proximity to a water zone, fracturing was stopped. With three of eight zones in this well requiring sand control, a pinpoint solution was delivered in stages by means of a pump through with a packer system [retrievable test treat squeeze (RTTS)] at the highest possible accuracy, thus ensuring treatment placement efficiency. The zones were also distanced from one another, requiring zonal isolation (i.e., mechanical isolation, such as bridge plugs, was not an option) as treatments were deployed. While there was a major challenge in terms of mobilization planning to complete this well during the peak of a movement control order (MCO) in Malaysia, optimal operations lead to a long-term sand control solution. Well unloading and test results upon well completion provided excellent results, highlighting good production rates with zero sand production. The groundwork processes of candidate identification down to the execution of sand consolidation and temporary isolation between zones are discussed. Technology is compared in terms of resin fluid system types. Laboratory testing on the core samples illustrates how the chemical consolidation process physically manifests. This is used to substantiate the field designs, execution plan, initial results, follow-up, lessons learned, and best practices used to maximize the life of a sand-free producer well. This success story illustrates potential opportunity in using sand consolidation as a primary method in the future.

Tacit Knowledge Sharing for System Integration

2020 ◽  
pp. 70-83
Author(s):  
Yawar Abbas ◽  
Alberto Martinetti ◽  
Mohammad Rajabalinejad ◽  
Lex Frunt ◽  
Leo A. M. van Dongen
Keyword(s):  
The Netherlands ◽  
Knowledge Sharing ◽  
Tacit Knowledge ◽  
System Integration ◽  
Lessons Learned ◽  
Complex Processes ◽  
Adequate Knowledge ◽  
Tacit Knowledge Sharing ◽  
Tacit Dimension

Sharing of tacit knowledge is a key topic of research within the knowledge management community. Considering its embodied nature, organizations have always struggled with embedding it into their processes. Proper execution of complex processes such as system integration asks for an adequate sharing of tacit knowledge. Acknowledging the importance of lessons learned for system integration and their presence in tacit and explicit form, a case study was conducted within the Netherlands Railways. It was determined that non-sensitivity to the tacit dimension of lessons learned has resulted in their lack of utilization. Consequently, LEAF framework was developed, where LEAF stands for learnability, embraceability, applicability, and findability. The framework suggests that addressing these four features collectively can eventually lead to an adequate knowledge-sharing strategy for lessons learned. Lastly, the chapter presents an example from the Netherlands Railways to emphasize the key role technological solutions of Industry 4.0 can play in facilitating tacit knowledge sharing.

Tacit Knowledge Sharing for System Integration

2021 ◽  
pp. 480-493
Author(s):  
Yawar Abbas ◽  
Alberto Martinetti ◽  
Mohammad Rajabalinejad ◽  
Lex Frunt ◽  
Leo A. M. van Dongen
Keyword(s):  
The Netherlands ◽  
Knowledge Sharing ◽  
Tacit Knowledge ◽  
System Integration ◽  
Lessons Learned ◽  
Complex Processes ◽  
Adequate Knowledge ◽  
Tacit Knowledge Sharing ◽  
Tacit Dimension

Sharing of tacit knowledge is a key topic of research within the knowledge management community. Considering its embodied nature, organizations have always struggled with embedding it into their processes. Proper execution of complex processes such as system integration asks for an adequate sharing of tacit knowledge. Acknowledging the importance of lessons learned for system integration and their presence in tacit and explicit form, a case study was conducted within the Netherlands Railways. It was determined that non-sensitivity to the tacit dimension of lessons learned has resulted in their lack of utilization. Consequently, LEAF framework was developed, where LEAF stands for learnability, embraceability, applicability, and findability. The framework suggests that addressing these four features collectively can eventually lead to an adequate knowledge-sharing strategy for lessons learned. Lastly, the chapter presents an example from the Netherlands Railways to emphasize the key role technological solutions of Industry 4.0 can play in facilitating tacit knowledge sharing.

A geomechanical approach for sanding risk assessment applied to three field cases for completion optimisation

2010 ◽  
Vol 50 (1) ◽  
pp. 623 ◽  
Author(s):  
Khalil Rahman ◽  
Abbas Khaksar ◽  
Toby Kayes
Keyword(s):  
Decision Making ◽  
Petroleum Industry ◽  
Cost Effective ◽  
Development Planning ◽  
Control Measures ◽  
Sand Production ◽  
Field Development ◽  
Well Completion ◽  
Sand Control ◽  
Production Prediction

Mitigation of sand production is increasingly becoming an important and challenging issue in the petroleum industry. This is because the increasing demand for oil and gas resources is forcing the industry to expand its production operations in more challenging unconsolidated reservoir rocks and depleted sandstones with more complex well completion architecture. A sand production prediction study is now often an integral part of an overall field development planning study to see if and when sand production will be an issue over the life of the field. The appropriate type of sand control measures and a cost-effective sand management strategy are adopted for the field depending on timing and the severity of predicted sand production. This paper presents a geomechanical modelling approach that integrates production or flow tests history with information from drilling data, well logs and rock mechanics tests. The approach has been applied to three fields in the Australasia region, all with different geological settings. The studies resulted in recommendations for three different well completion and sand control approaches. This highlights that there is no unique solution for sand production problems, and that a robust geomechanical model is capable of finding a field-specific solution considering in-situ stresses, rock strength, well trajectory, reservoir depletion, drawdown and perforation strategy. The approach results in cost-effective decision making for appropriate well/perforation trajectory, completion type (e.g. cased hole, openhole or liner completion), drawdown control or delayed sand control installation. This type of timely decision making often turns what may be perceived as an economically marginal field development scenario into a profitable project. This paper presents three case studies to provide well engineers with guidelines to understanding the principles and overall workflow involved in sand production prediction and minimisation of sand production risk by optimising completion type.

Numerical simulation of Sector Bond log and improved cement bond image

Geophysics ◽  
2012 ◽  
Vol 77 (4) ◽  
pp. D95-D104 ◽  
Author(s):  
Ruo-Long Song ◽  
Jin-Xia Liu ◽  
Chun-Hui Hou ◽  
Ke-Xie Wang
Keyword(s):  
Numerical Simulation ◽  
Finite Difference ◽  
Field Data ◽  
New Approach ◽  
Channel Size ◽  
Well Production ◽  
Well Completion ◽  
Bond Evaluation ◽  
Potential Channels ◽  
Acoustic Responses

The two principal functions of a primary cement job are to provide support for the casing and to provide hydraulic isolation between zones. A poor cement job may cause many issues during the well production. Therefore, cement bond evaluation is very important in well completion. The Sector Bond log (SBL) has been widely used for cement bond evaluation for years. The SBL tool has eight pairs of directional transmitter-receivers, which are equally distributed in azimuth and used for identifying channels and channel azimuths. To better understand SBL, using a parallel 3D finite difference algorithm, we numerically simulated acoustic responses of the SBL under a variety of cement bond scenarios and investigated the sensitivity of the integral amplitudes to channel size and its azimuth. We further developed a new approach to image potential channels in cement annulus using the integral amplitudes. The comparisons between conventional SBL images and the reprocessed ones using the new approach showed significant improvement on both synthetic and field data.

Use of seismic attributes and open-hole log data to characterize production variability in a fractured carbonate play: A case study from Madison County, Texas

2019 ◽  
Vol 7 (1) ◽  
pp. T167-T178
Author(s):  
Courtney Beck ◽  
Anna Khadeeva ◽  
Bhaskar Sarmah ◽  
Trey Kimbell
Keyword(s):  
Natural Fracture ◽  
Good Prediction ◽  
Fracture Density ◽  
Natural Fractures ◽  
Well Performance ◽  
Log Data ◽  
Well Production ◽  
Well Completion ◽  
Madison County ◽  
Fractured Carbonate

Understanding natural fracture systems is key for tight carbonate plays, in which production is dependent on secondary interconnected porosity networks. Locating geographic areas and stratigraphic sections with high natural fracture density and optimizing well locations and perforations to connect these fractures can enhance well performance and asset value. There is substantial production variation in the Cretaceous stacked carbonate play in East Texas, despite similarities in well completion and perforated intervals. Petrophysical property models did not explain the significant variation in well production; therefore, we have developed a multidisciplinary workflow combining seismic and log data with the goal of identifying faulting and natural fractures and understanding their effect on production. We used seismic discontinuity to map faults as the main indicator of presence of fractures. We calibrated triple combo logs with an image log to generate an indicator curve to identify natural fractures. The fracture indicator curve provided a good prediction of where natural fractures may occur, and discontinuity maps revealed a good correlation to well production. Furthermore, we concluded that drilling too closely to large faults negatively impacted production and correlated with increased water production. The workflow developed here can be used to optimize well placement in the stacked carbonate play of Madison County, Texas, and it can be applied to other fractured carbonate reservoirs.

Defining Heterogeneity and Compartmentalisation Predictions of Minor Reservoirs in Fluvial Environments: Geological and Dynamic Context

2021 ◽  
Author(s):  
Nur Azah Zulkifli ◽  
Lisa Claire Chisholm ◽  
Amy Mawarni M Yusoff ◽  
Nur Khairina Kosnon ◽  
Mohd Zubair Mohd Azkah ◽  
...  
Keyword(s):  
Seismic Analysis ◽  
Primary Objective ◽  
Lessons Learned ◽  
Reservoir Modeling ◽  
Well Performance ◽  
Reservoir Properties ◽  
Reservoir Prediction ◽  
Depositional Facies ◽  
Fundamental Study ◽  
Well Production

Abstract Reservoirs in MN Field comprise predominantly fluvial delta deposits. A number of reservoir modeling studies have been performed for major reservoirs, however, there are still challenges to be addressed. After 20 plus years of production, a project for minor reservoirs has been crafted based on the understanding and challenges of major reservoirs. The primary objective of this study was to improve the understanding of the uncertainties impacting the well performance and reservoir connectivity; and to find potential infill opportunities. A 2D conceptual modelling approach was used as a practical way to incorporate the static and dynamic data of logs, core, seismic and pressure data. Taking the lessons learned from the major reservoir performances, this study focused on the fluvial reservoir sedimentology to address and decrease the uncertainties through the different scales of heterogeneity. Consequently, depositional facies maps were developed with the integration of geophysical study and interpretation derived from seismic analysis. These integrated depositional facies maps were then further refined with the well production data and scenarios of multiple compartments from multiple iterations to fit into the conceptual models of this field. Refined paleo depositional maps for these minor reservoirs allowed for a better understanding on reservoir heterogeneities and further improved the geological understanding. This fundamental study can show us a more precise distribution and tendency of the sand and the scales of heterogeneity with different depositional facies. However, capturing and preserving the different levels of heterogeneities and compartmentalization is complex for some thin sand reservoirs which are below seismic resolution and have low correlation of reservoir properties-seismic response. Additionally, multiple compartments were inferred due to pressure difference and multiple contacts within a reservoir. This was further complicated by the uncertainty in log interpretation due to inadequacy of high confidence data (DST/fluid sampling), suppressed resistivity from shaly sands and below log resolution of thin beds. Despite of these issues and challenges, with integration of all the data available and rigorous team discussions; the minor reservoirs depo-facies, static and dynamic compartmentalization were finalized, leading to enhancement of reservoir prediction, communication and quality.

Downhole Annular Barrier Solution for Sustained Casing Pressure - Trinidad Case Study

2021 ◽  
Author(s):  
Jonathan Eugen Olsen ◽  
Wayne Hosein ◽  
Thomas Ringe ◽  
John David Friedli
Keyword(s):  
Quality Control ◽  
High Pressure ◽  
System Integration ◽  
Position Control ◽  
Hydraulic Testing ◽  
Line System ◽  
Precise Position ◽  
Electric Line ◽  
Sustained Casing Pressure ◽  
Casing Pressure

Abstract Objectives/Scope Downhole Annular Barrier (DAB) systems employed in intervention can correct integrity and conformance control issues during well lifecycle, extending the productive term in a safe and costeffective manner. These emergent wireline technologies come with unique challenges for logistics, quality control, and engineering, but can also provide solutions to difficult problems, with high value to spend ratio, in the non-rig intervention sector. The paper will review one such successful intervention, completed offshore Trinidad W.I., in a gas well presenting long term Sustained Casing Pressure (SCP). The desired end state of the well was A-Annulus at 0 psi SCP, which would return the well to a safe state and permit a planned infrastructure project to move ahead. Methods, Procedures, Process Operational objective was isolation of the casing annulus pressure from the source by injecting epoxy into the annular space at depth, forming a 360-degree pressure barrier. The project can be broken down into three main sections. The paper and presentation will address each section with its specific challenges, learnings, and outcomes: Onshore Epoxy and Tool Preparation Each Downhole Annular Barrier job employs a custom recipe epoxy suited to the planned logistics timing and expected bottomhole conditions. Quality control of the epoxy recipe and mixing process as well as temperature control of the batch after mixing is key to the sealing properties of the final epoxy plug. • An Epoxy Lab and Mixing Station was dismantled, air freighted, and reconstituted in Trinidad near to the field operations port. Special insulated offshore CCU were built to transport and contain filled epoxy canisters while maintaining low temperature requirements (near to 0 deg C for up to 30 days). • Build and System Integration Testing (SIT) of the downhole system (anchoring, stroking, hydraulic testing, perforation, and injection) with the electric line system (conveyance, telemetry, power). Offshore Job Execution The DAB system employed is designed to complete multiple operations in a single trip into the well, including perforating and high-pressure epoxy injection, with precise position control and monitoring. This is made possible with the multi-function modular tool. The operation was dynamic by design and contingencies were implemented based on the well response. Multiple epoxy annular plugs were placed into the A Annulus at depth, with high pressure injection. Results, Observations, Conclusions Well Response and Assessment Utilizing advanced annular surface monitoring technology and PvT analysis, precise assessment of the annulus pressure build was recorded throughout the operation. Once the project criteria were met, the operation was successfully concluded.

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