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Collaborating Authors
Results
- South America > Brazil (1.00)
- South America > Argentina (1.00)
- Oceania > Australia (1.00)
- (39 more...)
- Summary/Review (1.00)
- Research Report (1.00)
- Personal > Honors (1.00)
- (6 more...)
- Phanerozoic > Paleozoic (0.67)
- Phanerozoic > Cenozoic (0.67)
- Geology > Sedimentary Geology > Depositional Environment (1.00)
- Geology > Mineral (1.00)
- Geology > Geological Subdiscipline > Stratigraphy (1.00)
- (8 more...)
- Transportation (1.00)
- Media (1.00)
- Materials > Metals & Mining (1.00)
- (14 more...)
- South America > Colombia > Meta Department > Llanos Basin > Cano Sur Block > Carbonera Formation (0.99)
- South America > Brazil > Campos Basin (0.99)
- South America > Argentina > Patagonia > Neuquรฉn > Neuquen Basin (0.99)
- (105 more...)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Shale gas (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic modeling (1.00)
- (17 more...)
- Government > Regional Government > Asia Government > Middle East Government > Qatar Government (0.96)
- Energy > Oil & Gas (0.96)
- Facilities Design, Construction and Operation > Natural Gas Conversion and Storage > Liquified natural gas (LNG) (0.96)
- Management > Professionalism, Training, and Education > Communities of practice (0.60)
- Data Science & Engineering Analytics > Information Management and Systems > Knowledge management (0.60)
- Management > Professionalism, Training, and Education > Communities of practice (0.60)
- Data Science & Engineering Analytics > Information Management and Systems > Knowledge management (0.60)
How Close is Too Close? Saving Undrillable Slots Through Top-Hole Jetting and Drilling in Al-Shaheen Field, Offshore Qatar
Cousso, Olivier (North Oil Company) | Bilal, Ahmed (North Oil Company) | Sikal, Anas (PathControl) | Momot, Fabien (PathControl) | Cullen, Matthew (Schlumberger) | Bejaoui, Fakhreddine (Schlumberger) | El Abid, Ammar (Schlumberger) | Aleshin, Alexey (Schlumberger)
Abstract A new joint venture operator, established to take over an existing strategic producing field with ongoing drilling operations, took the opportunity to design a new collision avoidance standard, based on the latest WPTS (Wellbore Positioning Technical Section) probability method collision avoidance rules. This has been combined with an innovative execution approach to safely and successfully unlock slots on congested platforms and drill some of the most difficult well trajectories in this complex field from the very first well. Al Shaheen field, offshore Qatar, is one of the most challenging fields worldwide in terms of collision avoidance. When drilling extended-reach wells from the last-remaining and most challenging slots, with top-hole separation as low as three feet centre-to-centre at the conductor pipe shoe, close collaboration with all parties is required to manage collision risk, minimise production loss, and ensure all well objectives are achieved. The execution strategy includes simple jetting and rotating BHA designs for 3D-profile trajectories, remote real-time monitoring including 24/7 survey QA/QC and validation, and mitigation through a decision-making matrix customised for the specific drilling challenges. The platform configuration and challenges in the drilling environment are discussed, together with the theory of the selected collision avoidance rule and the resulting risk matrix. A brief review of why jetting is selected as the only allowable drilling technique in major risk situations plus the story of the evolution of Al Shaheen jetting BHAs follows. Finally, three case studies of top-hole operations describe the practical application of the techniques discussed. The selected case studies describe the jetting operation from the deepest CP (Conductor pipe), the deepest well jetted, and the first 23-in jetting operation carried out by the operator. The combination of risk analysis through genuine probabilistic considerations, jetting operations, and appropriate oversight has been used successfully for more than two years and has allowed over twenty of the remaining, most challenging, slots to be saved, ensuring the assets are optimised in the ongoing economically-constrained environment. The WPTS have now published their proposed industry-standard probability-based collision-avoidance rule. These case-history examples of a similar rule from extreme close-approach drilling will assist other operators considering uptake of the new guidelines, as will the risk matrix developed by the operator. In addition, the jetting technique used as a major mitigation factor is seldom used today in the industry and the lessons learned in jetting BHA design have already benefited another operator in the region.
- Well Drilling > Well Planning > Trajectory design (1.00)
- Well Drilling > Drilling Operations (1.00)
- Management > Risk Management and Decision-Making (1.00)
- (2 more...)
- Management > Professionalism, Training, and Education > Communities of practice (0.44)
- Data Science & Engineering Analytics > Information Management and Systems > Knowledge management (0.44)
Abstract The control of inorganic scale deposition within production wells by deployment of scale squeeze treatments is a well-established method for both onshore and offshore production wells. Over the past 25 years the science of designing and optimising these treatments has advanced significantly with a better understanding of chemical/rock interaction, more effective modelling software to design the treatments and improved analysis methods for the determination of returning residual concentrations. Scale squeeze treatments have in general been designed to treat between 6 to 12 months of water production before either the production layer or bulk produced water composition falls below minimum inhibitor concentration (MIC). In this paper examples of the process followed to design treatments for 24 months produced water for three offshore fields (North Sea, West Africa and Middle East) are outlined. Factors that have influenced the change from 12 to 24 months squeeze treatments include changing MIC values, rising operation expenditure related to subsea vs platform deployment costs and in all cases assessing total operational cost vs simply chemical costs alone. This paper presents the field treatment designs from 4 case study fields, changing MIC values based on produced water composition which impacts chemical volumes required. The balance between cost of operation to deploy the chemical treatments to subsea vs platform wells are discussed. The implication of deferred oil associated with delayed production during pumping and post squeeze well clean-up was also considered in the design process for these wells. These case studies describe squeeze treatments which in certain wells treat over 25,000,000 bbls to MIC. The paper outlines the elements of the process that should be considered/reviewed when making the decision to change from the conventional 12 months to 24 months squeeze treatment. Designs and field results from three oil producing basins, each with different cost drivers, have been used to illustrate how it is possible to maintain effective scale management through the life cycle of these production wells.
- Europe > United Kingdom (1.00)
- North America > United States > Texas (0.93)
- Europe > Norway > North Sea (0.67)
- Asia > Middle East > Qatar > Arabian Gulf (0.24)
- Energy > Oil & Gas > Upstream (1.00)
- Water & Waste Management > Water Management > Constituents > Salts/Sulphates/Scales (0.54)
- South America > Brazil > Campos Basin (0.99)
- North America > United States > Mississippi > Improve Field (0.99)
- Europe > United Kingdom > North Sea > North Sea Basin (0.99)
- (15 more...)
- Production and Well Operations > Well Operations and Optimization (1.00)
- Production and Well Operations > Well Intervention (1.00)
- Production and Well Operations > Production Chemistry, Metallurgy and Biology > Inhibition and remediation of hydrates, scale, paraffin / wax and asphaltene (1.00)
- (4 more...)
Abstract This article attempts to summarize measures that are required to be adopted in order to have safe drilling practices mainly in unstable shale formation and have a smooth landing section in target reservoir below the shale. For the last three years in North Kuwait, the number of geo-steering jobs increased significantly and some encountered problems while drilling Wara shale that may end up in losing tools and eventually the hole itself. This paper focuses on information regarding problems encountered in geo-steering jobs and the best practices followed to achieve goals. Stratigraphically, Wara shale lies underlying Tuba and overlying Mauddud carbonates. It has thickness variation in between 80 to 110 feet TVD. Wara shale in North Kuwait is generally unstable and very sensitive to mud properties and creates instability of the wellbore. A wide range of drilling data from well placement jobs were documented and analyzed in order to get an idea of the behavior of shale section, how to drill safely across this layer and mitigate possible risks that may harm the well as well as the tool. Detailed scrutiny was done to compare the drilling parameters, log responses, inclination and trajectory direction between stable and unstable wells. The results were integrated with regional tectonic regime in the area. The methodology and learning curve continuously improved with assimilation of new drilling data and information. Integrated study on all aspects in drilling that involving geo-steering engineers, drilling team, geologists and field engineers on-site has enhanced the ability to understand the situation in the hole and ultimately able to provide faster decision. It was observed that there is strong relationship of building inclination, direction of the well and mud weight in some wells when crossing Wara shale. Wells that have East - West or Northwest - Southeast direction tend to be unstable when compared to wells in North - South or Northeast - Southwest direction. Low incident angle (high inclination) will mostly cause more problems in drilling than high incident angle due to longer section of exposure as well as overburden. Compressional tectonic regime of the area dictate the recommendation of well trajectory should go towards maximum horizontal stress. Recommended to cross it with low inclination and consequently approaching the target reservoir with high dogleg severity tool was to maintain the stability of the wellbore. These findings will help service provider and client to make proper planning, adopt best practice, take proper decision and thereby successfully execute well operations. Indeed saving rig and delivery time that fulfill business objectives as planned.
- Asia > Middle East > Kuwait > Jahra Governorate (0.66)
- Asia > Middle East > Qatar > Arabian Gulf (0.40)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > Sabriyah Field > Marrat Formation > Upper Marrat Formation (0.99)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > Sabriyah Field > Marrat Formation > Sargelu Formation (0.99)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > Sabriyah Field > Marrat Formation > Sabiriyah Mauddud (SAMA) Formation (0.99)
- (39 more...)
- Well Drilling > Wellbore Design > Wellbore integrity (1.00)
- Well Drilling > Well Planning > Trajectory design (1.00)
- Well Drilling > Drilling Operations (1.00)
- (5 more...)
Technology Focus More than half of all existing wells are estimated to require sand control or sand management throughout their lifetime, including unconsolidated sandstone in conventional reservoirs or flowback in unconventional reservoirs. The majority of recent major hydrocarbon discoveries, from Africa (Mozambique, Angola, and Tanzania), transcontinental countries (Egypt), North America (US and Canada), to Far East Asia (Malaysia), are offshore with high-permeability soft formation sands. Approximately half of them are gas-bearing reservoirs. High-flow-rate gas wells are particularly susceptible to sand production. High-velocity or turbulent fluid flow generates large drag forces, dislodging unconsolidated sand particles. The free-flowing particles can erode downhole and surface equipment, including well-control barriers. In a worst-case scenario, this can lead to dangerous uncontrolled production. To ensure successful sand management, a multidisciplinary engagement is necessary. The teams should be able to predict sanding tendencies, detect the sanding locations, select appropriate downhole sand-management and -control devices, and implement the best operating practices for the life of the well. Because of the current downturn, operators are shifting their efforts to the revitalization of existing wells in order to squeeze more production from depleted reservoirs. The same holistic sand-management tactic should be applied to remedial sand control. In summary, production from sand-prone reservoirs is a daunting task, with formidable challenges. Sand management and control remain as an old problem but with new challenges because of the suppressed oil and gas prices. Cost-saving and value-adding solutions are vital now more thanย ever. For more information, read the featured papers, recommended additional reading, and other publications at OnePetro. Recommended additional reading at OnePetro: www.onepetro.org. SPE 181596 Defining Sand Control in an Uncharted Frontier: A Case Study on the Zawtika Field Development in Myanmar by Graham Grant, PTTEP International, et al. SPE 181360 Case History: Integrated Approach to Sand Management and Completion Evaluation for Sand Producer in a Mature Field, North Sea by M. Ruslan, Dong Oil and Gas, et al. SPE 182511 New Criteria for Slotted-Liner Design for Heavy-Oil Thermal Production by Mahdi Mahmoudi, University of Alberta, et al.
- Africa (1.00)
- North America > Canada > Alberta (0.57)
- Asia > Myanmar > Andaman Sea > Gulf of Martaban (0.26)
- Asia > Middle East > Qatar > Arabian Gulf (0.26)
- Well Completion > Sand Control (1.00)
- Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Flow in porous media (0.57)
- Management > Professionalism, Training, and Education > Communities of practice (0.57)
- Data Science & Engineering Analytics > Information Management and Systems > Knowledge management (0.57)
Abstract The talent gap in the E&P industry is an ongoing issue that is expected to persist due to attrition in the current workforce and the increasing percentage of junior employees. As result of this, there is not enough overlap between the two generations to pass knowledge and experience; therefore, knowledge and experience may be lost. Under the new oil and gas business realities of highly volatile prices and increased operating costs, the national oil companies (NOCs) require a workforce that has a new way of thinking to overcome current challenges and unpredictable market conditions. Effectively and efficiently resolving the talent gap should lead to greater productivity by increasing production and decreasing operating costs. This paper traces the origins of the talent gap and the events that led to current shortages. The proposed strategy for NOCs to resolve the talent gap has four main pillars: accelerating junior employees' development, leveraging the experience of senior staff, a structured knowledge sharing system, and new methods for filling current talent vacancies. Each of these pillars is discussed in detail and corrective action items are proposed. The successful adaptation and implementation of this strategy should ensure E&P companies' business continuity and will ultimately help in knowledge preservation within large NOCs.
- Asia > Middle East > Saudi Arabia (0.28)
- Asia > Middle East > Qatar (0.28)
- Asia > Middle East > UAE > Abu Dhabi Emirate > Abu Dhabi (0.15)
- Management > Professionalism, Training, and Education > Personnel competence (1.00)
- Data Science & Engineering Analytics > Information Management and Systems > Knowledge management (0.88)
- Management > Professionalism, Training, and Education > Communities of practice (0.67)
Coupling Integrated Data Management with Reservoir Surveillance Workflows for Giant Mature Field in Qatar
Khalifa, O. M. (Qatar Petroleum) | Rais, T. A. M (Qatar Petroleum) | El Maadi, A. (Qatar Petroleum) | Abdullah Sani, R. (Qatar Petroleum) | Mahrous, E. K. (Qatar Petroleum) | Al-Marri, Balsam (Qatar Petroleum)
Abstract Dukhan, a giant mature onshore field in Qatar, presents a unique challenge to manage multidimensional data within surveillance workflows. A unified data infrastructure is the key enabler for proper field performance monitoring, bridging operational locations to decision-making centers. In this respect, Qatar Petroleum (QP) is integrating reservoir and data management workflows into a single hub that shifts linear workflows into real-time decision-making and action-oriented processes. The strategic advantage of this approach is to provide technology and data real-time, readily available for the key decision-makers. As a strategic initiative, implementation has presented unique challenges in infrastructure modification and technology uptake. The envisaged solution architecture lies on capabilities of QP's workflows in delivering web components, leveraging multifunctional collaboration, and closing operational gaps within the surveillance workflows. The solution is delivered through a unified platform where periodic/sporadic production information is tied to asset operational models across different sub-systems integrating all surveillance workflows. The benefits include a fully collaborative environment, a solid data management system to enable timely decisions, and improved shortfall management. Integrating people and processes with the right balance of technology results in enhanced operational efficiencies and recoveries. Despite challenges, QP has gained significant advantages in early adoption and development of this technology, and its implementation has revolutionized the approach to surveillance. In view of the above, the combination of the above aspects resulted in significant increase in compliances, minimized mitigation turnaround time and generated better collaboration within operating units. This paper describes experiences and challenges of QP project from conception through implementation integrating people and process with the right balance of technology across field operations and how it has resulted in enhanced operational efficiency and production recovery with full asset awareness.
- North America > United States > Arkansas > Smart Field (0.99)
- Asia > Middle East > Qatar > Arabian Basin > Arabian Gulf Basin > Dukhan Field (0.99)
- Management > Risk Management and Decision-Making (1.00)
- Management > Professionalism, Training, and Education > Communities of practice (1.00)
- Management > Asset and Portfolio Management > Field development optimization and planning (1.00)
- (2 more...)