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Habibi, Ali (University of Alberta) | Fensky, Charles E. (Blue Spark Energy) | Perri, Mike (Blue Spark Energy) | Roostaei, Morteza (RGL Reservoir Management, Inc.) | Mahmoudi, Mahdi (RGL Reservoir Management, Inc.) | Fattahpour, Vahidoddin (RGL Reservoir Management, Inc.) | Zeng, Hongbo (University of Alberta) | Sadrzadeh, Mohtada (University of Alberta)
Previous studies showed that different parameters influence the plugging of completion tools. These parameters include rock mineralogy, reservoir-fluid properties, and type of completion tools. Although different methods have been used for unplugging these tools, there is still debate regarding the performance of these methods on damage removal. In this study, we assessed the performance of high-power shock waves generated from an electrohydraulic-stimulation (EHS) tool on cleaning completion tools plugged during oil production. These devices were extracted from different wells in Canada, Europe, and the US. First, we quantified the extent of cleaning for the plugged slotted liners using the EHS tool at the laboratory scale. Next, we analyzed the mineral composition of the plugging materials removed after the treatment by conducting scanning electron microscopy (SEM) with energy dispersive X-ray spectroscopy (EDS), inductively coupled plasma mass spectroscopy (ICP-MS), colorimetric, and dry-combustion analyses. Finally, we reviewed the pulsing-stimulation-treatment results applied to several field case studies. The results of unplugging slotted liners at the laboratory scale showed that up to 28.5% of the plugged slots are cleaned after 120 pulses of shock waves. The mineral-characterization results showed that the main plugging materials are calcite, silicates, and iron-based components (corrosion products). The cleaning performance (CP) of the EHS tool increases by increasing the number of pulses and the output energy (OE) applied to the tool. The CP parameter is high at (i) high concentrations of carbonates, barium (Ba)-based components, and organic matter, and (ii) low concentrations of corrosion products and sulfates. The results of field case studies showed that the cleaning of the EHS tool is not limited to the sand-control devices and it can clean other tools that are less accessible for other techniques, such as subsurface safety valves. This paper provides a better understanding of the performance of shock waves on damage removal from plugged completion tools. The results could open new insight into the applications of shock waves for cleaning the completion tools.
The ever-increasing need for resilient strategies demands the supreme understanding of business uncertainties and the execution risks. For the National Oil Companies like, ADNOC, the annual reservoir performance review (ARPR) is a process of paramount importance, as it provides a holistic overview of the reservoir performance status for each ADNOC field on yearly basis. It unfolds the subsurface performance issues, uncertainties and risks, and steers the decisions of Business Plan sanctions.
The ARPR execution demands a tremendous amount of time and effort to assimilate information and create a consolidated decision support package. In the absence of an automated process, the creation of insightful analytics, proper tracking of actions and maturation of value-driven opportunities become unmanageable. Thus, the automation of the process asserted to demonstrate a significant reduction of the data preparation time, increased multidisciplinary collaboration, centralized data archiving and integrated dashboard generation.
A multidisciplinary team of ADNOC's subject matter experts joined forces to develop a fit-for-purpose automated solution (
The solution enables assigning tasks to users at various supervisory and coordinating levels through an automated governance system. It provides means to monitor the progress of the work, approve the content of Elements and Sections, and review the concatenated ARPR document for final approval. All the integrated analyses get stored into the corporate repositories for any future utilization in data mining and advance analytics workflows.
The automated solution (
Al Rumaithi, Ebraheem (Co-Author - Al Dhafra Petroleum) | Adi, Mohamad Bara (Co-Author - Al Dhafra Petroleum) | Al Obeidli, Ibrahim (Co-Author - Al Dhafra Petroleum) | Akhtar, Mujahid (Author - Al Dhafra Petroleum ADNOC Group)
An alternate strategies were developed for achieving early oil production from partially commissioned oil gathering and export facilities to minimize the project delay and to accelerate the production with-out compromising health, safety and environment (HSE) and integrity requirements. Extensive technical and operational reviews conducted while exercising agile approach. Adopting agile approach may benefit other upstream companies and give them with necessary insights to overcome the challenges and realize the benefits from reviewing the lessons learned.
Unlike conventional approach, where ready for commissioning (RFC) is considered with full readiness of production facilities, we added first oil date earlier than RFC with min. required facilities. The schedule risk analysis showed several months delay due to late site mobilization, late material deliveries, and inadequate construction progress. As a result, stakeholders asked to explore alternative strategies to accelerate the production. Early production scenarios were developed, evaluated while considering associated risks, hazard and operability study (HAZOP), constructability and simultaneous operations (SIMOPS). An optimal agile strategy was selected by stakeholders. A block flow diagram with partial facilities with natural flow was approved and construction works were prioritized accordingly.
The agile approach contributed in achieving early production several months ahead comparing to RFC date and forecast delays. During initiation of alternative strategies evaluation, there was little resistance from stakeholders who think that adopting agile approach may not be beneficial and will interrupt project progress. But, it overcame once benefits were realized during discussions, workshops and negotiations where key stakeholders buy-in the alternative strategy. Team morale improved and energized after achieving early production. It was celebrated at organization level incl. coverage in local and international media. Sub-surface and surface data was reconciled to support early oil with natural flow with min. number of wells and production increased progressively. The contractor agreed to be strict in brownfield demarcation to minimize impact on operations, and construction works due to simultaneous operations (SIMOPS), etc. A proper risk assessment & mitigation, fast decision making, and one team spirit were essential component in unlocking the potentials of agile approach. Based on successful results achieved by adopting alternative strategy and agile approach enabled our company achieved early production within 19 months in-spite of all challenges occurred during first 13 months of the project. And finally senior management leadership, guidance and support played a key role in the achieving the agreed milestone.
The early oil production by adopting agile approach without waiting for full facilities readiness is somehow novel. By sharing our experience with challenges, and lesson learned may enable others to unlock the potential of such alternative strategies. We can include such scope statement during initiation phase in the future projects that can empower operating companies to achieve the same results with-out going through the learning curve and optimize the schedule to achieve early production.
Rachapudi, R. V. (ADNOC Onshore) | Al-Jaberi, S. S. (ADNOC) | Al Hashemi, M. (ADNOC) | Punnapala, S. (ADNOC Onshore) | Alshehhi, S. S. (ADNOC Onshore) | Talib, N. (ADNOC Onshore) | Loayza, A. F. Jimenez (ADNOC Onshore) | Al Nuimi, S. (ADNOC Onshore) | Elbekshi, A. (ADNOC Onshore) | Quintero, F. (ADNOC Onshore) | Yuliyanto, T. (ADNOC Onshore) | Abd Rashid, A. Bin (ADNOC Onshore) | Alkatheeri, F. Omar (ADNOC Onshore) | Gutierrez, Daniel (ADNOC Onshore) | Chehabi, W. (Fishbone A/S) | Hussain, Ali Ba (ADNOC Onshore)
Productivity enhancement of tight carbonate reservoirs (permeability 1-3 md) is critical to deliver the mandated production and to achieve the overall recovery. However, productivity improvement with conventional acid stimulation is very limited and short-lived. Tight reservoirs development with down spacing and higher number of infill wells can increase the oil recovery. Nevertheless, poor vertical communication (Kv/Kh < 0.5) within the layered reservoir is still a challenge for productivity enhancement and needs to be improved.
First time successful installation of fishbone stimulation technology at ADNOC Onshore targeted establishing vertical communication between layers, in addition to maximizing the reservoir contact. Furthermore this advanced stimulation technology connects the natural fractures within the reservoir, bypasses near well bore damage and allows the thin sub layers to produce. This technology requires running standard lower completion tubing with Fishbone subs preloaded with 40ft needles, and stimulation with rig on site. This paper presents the case study of the fishbone stimulation technology implemented at one of the tight-layered carbonate reservoir.
A new development well from ADNOC Onshore South East field was selected for implementation of this technology. The well completion consisting of 4 ½ liner with 40 fishbone subs was installed, each sub containing four needles at 90 degrees phasing capable of penetrating the reservoir up to 40 ft. While rig on site, acid job was conducted for creating jetting effect to penetrate the needles into the formation. Upon completion of jetting operation, fishbone basket run cleaned the unpenetrated needles present in the liner to establish the accessibility up to the total depth. Overall, application of this technology improved the well production rate to 1600 BOPD compared to 400 BOPD of production from nearby wells in the same PAD and reservoir. In addition the productivity of the candidate well improved by 2.5 times with respect to near-by wells in the same PAD. Currently, long-term sustainability testing preparation is in progress. This paper provides the details of candidate selection, completion design, technology limitations, operational challenges, post job testing and lessons learned during pilot implementation. In summary, successful application of this technology is a game changer for tight carbonate productivity enhancement that improves the overall recovery along with optimizing the drilling requirements. Currently, preparation for implementation of 10 pilots in one of the asset at ADNOC Onshore fields is in progress.
Sabahi, Atiya (Petroleum Development Oman) | Rahbi, Said (Petroleum Development Oman) | Harthi, Mahmood (Petroleum Development Oman) | Choudhury, Suryyendu (Petroleum Development Oman) | Darmaki, Faisal (Petroleum Development Oman) | Lawati, Ali (Petroleum Development Oman) | Ghatrifi, Suhaib (Petroleum Development Oman) | Mahrouqi, Iman (Petroleum Development Oman) | Morianta, Marpaung (Petroleum Development Oman) | Abri, Yaqoob (Petroleum Development Oman) | Al-Jumah, Ali (Petroleum Development Oman)
The objective of this study is to evaluate and de-risk the extension of the Kahmah Group, which is a newly identified carbonate extension in the Eastern part of XX field, and to assess and unlock further appraisal and development opportunities.
Eastern field correlation was done by correlating the wells that has encountered Kahmah carbonate, the ones showing low Gamma Ray (GR) traces. Well correlation was done mainly on Petrophysical properties of three vertical penetrations that show distinct and abrupt change from high GR (Base Nahr Umr Shale and/or Mahwis sandstones) to low GR reflecting Kahmah carbonates.
Based on the thicknesses of Kahmah based on the vertical well data and commercial oil seen in all wells in the vicinity, thickness and expected oil distribution maps were created.
The main findings from the correlation are: 1) Kahmah reservoir is divided into two pays and two non-pays zones as seen in XX-1H1. 2) The reservoir is thickest around XX-1 and thins out toward -10 to the south and disappears completely in XX-5 to the north, portraying a wedge- shape.
Kahmah reservoir varies in thickness, with thickest interval encountered in XX-1 with 11m. The reservoir thins out towards the edge closer to -10 confirming the wedge-like structure.
A conceptual understanding has been incorporated in generating cross-sections portraying and proving the wedge-shape structure of Kahmah.
Like any other new formation development, many uncertainties are associated with Kahmah development like formation extension, reservoir/fluid properties, pressure behaviour and others.
The key observations from this project can be summarized as following: Different packages of reservoir. May be of different or similar properties Extension of Kahmah towards northern part of XX field is still highly uncertain Continuity of Kahmah Reservoir is uncertain Reservoir pressure and communication with Mahwis formation need to be evaluated Reservoir and fluid properties also need to be evaluated
Different packages of reservoir. May be of different or similar properties
Extension of Kahmah towards northern part of XX field is still highly uncertain
Continuity of Kahmah Reservoir is uncertain
Reservoir pressure and communication with Mahwis formation need to be evaluated
Reservoir and fluid properties also need to be evaluated
Main oil line (MOL) pumps are responsible to deliver the partially stabilized crude oil from an offshore oilfield to a processing and storage facility where oil is exported through a loading station. MOL pump is categorized as a critically rated machine due to the fact that the consequences of its failure leads to major business and operational interruption, mainly production loss. This paper studies a failure prevention approach of MOL pump due to excessive vibration using actual site measurements, engineering test runs, and finite element analysis to predict the failure and maximize pump reliability.
This study presents a case of a MOL pump operating with vibration levels, at the drive-end bearing housing of the electric motor driver, beyond the allowable limits. This was initially experienced during the Factory Acceptance Test at the vendor premises. Vendor carried out corrective measures to overcome this unacceptable mechanical condition including, baseplate leveling, soft-foot check, rotor balancing and alignment. However, no significant improvements were achieved with these measures. Nevertheless, the pump package was sent to the construction yard to avoid delays to the project, at which the vibration issue was persisted leading to availability and reliability concerns. A detailed three-dimensional finite element (FE) model of the pump baseplate is built to simulate its dynamic behavior. Actual site vibration survey was carried out and measurements were collected, analyzed and compared to the FE predictions. Mitigation measures to overcome this excessive vibration are provided.
The results of the analysis show that localized resonance of the electric motor supporting beams at the baseplate are the main reason of the excessive vibration, which are transmitted to the motor bearing housing. The FE simulations were used to predict the system’s natural frequencies in the working frequency range. The calculated natural frequencies and mode shapes of the baseplate are verified against vendor calculations and actual site measurements. In order to reduce the vibration to allowable levels, additional steel plates were added with pre-specified mass, determined using simplified spring-mass system model, at a specific location on the resonating beams, mimicking the behavior of a dynamic absorber. The location and mass of this dynamic absorber were fine-tuned during site testing trials, and the vibration amplitude at the initial resonant peak was greatly reduced achieving allowable vibration level. Hence, the risk of equipment failure due to high vibration is eliminated.
The impact of weld residual stresses, pre-stressed structural components or distortions on the dynamic behavior of structures is not well recognized. This study utilizes in-depth advanced engineering analysis techniques to enhance the reliability of critical equipment and prevent its failure due to excessive vibrations.
Decisions in E&P ventures are affected by Bias, Blindness, and Illusions (BBI) which permeate our analyses, interpretations and decisions. This one-day course examines the influence of these cognitive pitfalls and presents techniques that can be used to mitigate their impact. Bias refers to errors in thinking whereby interpretations and judgments are drawn in an illogical fashion. Blindness is the condition where we fail to see an unexpected event in plain sight. Illusions refer to misleading beliefs based on a false impression of reality. All three can lead to poor decisions regarding which work to undertake, what issues to focus on, and whether to forge ahead or walk away from a project. Strategic thinking and planning are key elements in an organisation’s journey to maximise value to shareholders, customers, and employees. Through this workshop, attendees will go through the different processes involved in strategic planning including the elements of organisational SWOT, business scenario and options development, elaboration of strategic options and communication to stakeholders. Examples are provided including corporate, business unit and department case studies. This seminar will teach participants how to identify, evaluate, and quantify risk and uncertainty in everyday oil and gas economic situations. It reviews the development of pragmatic tools, methods, and understandings for professionals that are applicable to companies of all sizes. The seminar also briefly reviews statistics, the relationship between risk and return, and hedging and future markets.
SPE, through its Energy4me programme, will present a free one-day energy education workshop for science teachers (grades 8–12). A variety of free instructional materials will be available to take back to the classroom. Educators will receive comprehensive, objective information about the scientific concepts of energy and its importance while discovering the world of oil and natural gas exploration and production. Energy4me is an energy educational public outreach programme that highlights how energy works in our everyday lives and promote information about career opportunities in petroleum engineering and the upstream professions. SPE’s Energy4me programme values the role teachers and energy professionals play in educating young people about the importance of energy.
Learn more about training courses being offered. Learn more about training courses being offered. This course covers the fundamental principles concerning how hydraulic fracturing treatments can be used to stimulate oil and gas wells. It includes discussions on how to select wells for stimulation, what controls fracture propagation, fracture width, etc., how to develop data sets, and how to calculate fracture dimensions. The course also covers information concerning fracturing fluids, propping agents, and how to design and pump successful fracturing treatments. Learn more about training courses being offered. Current and future SPE Section and Student Chapter leaders are invited to engage and share.