The SPE has split the former "Management & Information" technical discipline into two new technical discplines:
- Data Science & Engineering Analytics
The SPE has split the former "Management & Information" technical discipline into two new technical discplines:
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The Abu Dhabi National Oil Company (ADNOC) and the Abu Dhabi National Energy Company (TAQA) have announced a major project requiring an investment of up to 2.4 billion to build a sustainable water supply for ADNOC's onshore operations. The infrastructure initiative includes the construction of a centralized seawater treatment facility and transportation network for the Bab and Bu Hasa fields in Abu Dhabi which combine to produce more than 1 million B/D. In 2021, ADNOC said it would spend more than 300 million on a multiyear project to install remotely controlled production systems in up to 260 conventional and unconventional wells in the Bu Hasa field. The Bab field has a capacity of over 450,000 B/D and is in the midst of a major enhanced oil recovery project that aims to increase production capacity to 485,000 B/D. The major capital program planned for both fields is seen as part of ADNOC's wider strategy to boost the UAE's production from 4 million to 5 million B/D by 2030.
Al-Riyami, N. (Exebenus, Stavanger, Norway) | Revheim, O. (Exebenus, Stavanger, Norway) | Robinson, T. S. (Exebenus, Stavanger, Norway) | Batruny, P. (PETRONAS Carigali, Kuala Lumpur, Malaysia) | Meor Hakeem, M. H. (PETRONAS Carigali, Kuala Lumpur, Malaysia) | Tze Ping, G. (Faazmiar Technology Sdn Bhd, Kuala Lumpur, Malaysia)
Abstract O&G operators seek to reduce CAPEX by reducing unit development costs. In drilling operations this is achieved by reducing flat time and bit-on-bottom time. For the last five years, we have leveraged data generated by drilling operations and machine learning advancements in drilling operations. This work is focused on field test results using a real-time global Rate of Penetration (ROP) optimization solution, reducing lost time from sub-optimal ROPs. These tests were conducted on offshore drilling operations in West Africa and Malaysia, where live recommendations provided by the optimization software were implemented by the rig crews in order to test real-world efficacy for improving ROP. The test wells included near-vertical and highly deviated sections, as well as various formations, including claystones, sandstones, limestones and siltstones. The optimization system consisted of a model for estimating ROP, and an optimizer algorithm for generating drilling parameter values that maximize expected ROP, subject to constraints. The ROP estimation model was a deep neural network, using only surface parameters as inputs, and designed to maximize generalizability to new wells. The model was used out-of-the-box, with no specific retraining for the field testing. During field-tests, increased average ROP was observed after following recommendations provided by the optimizer. Compared to offset wells, higher average ROP values were recorded. Furthermore, drilling was completed ahead of plan in both cases. In the Malaysian test well, following the software's advice yielded an increase in ROP from 10.4 to 31 m/h over a 136 m drilling interval. In the West Africa well, total depth was reached ∼24 days ahead of plan, and ∼2.4 days ahead of the expected technical limit. Importantly, the optimization system provided value in operations where auto-driller technologies were used. This work showcases field-test results and lessons learnt from using machine learning to optimize ROP in drilling operations. The final plug-and-play model improves cycle efficiency by eliminating model training before each well and allows instantaneous, real-time intervention. This deployable model is suitable to be utilized anytime, anywhere, with retraining being optional. As a result, minimizing the invisible lost time from sub-optimal ROP and reducing costs associated with on-bottom drilling for any well complexity and in any location is now part of the standard real-time operation solutions. This deployment of technology shows how further optimization of drilling time and reduction in well cost is achievable through utilization of real time data and machine learning.
Sulaiman, A. Y. (Adnoc Offshore, Abu Dhabi, United Arab Emirates) | AlHammadi, I. (Adnoc Offshore, Abu Dhabi, United Arab Emirates) | Al Ali, S. (Adnoc Offshore, Abu Dhabi, United Arab Emirates) | El-Sheikh, H. (Adnoc Offshore, Abu Dhabi, United Arab Emirates) | Al Ghafeli, S. K. (Adnoc Offshore, Abu Dhabi, United Arab Emirates) | Shokry, A. (Adnoc Offshore, Abu Dhabi, United Arab Emirates) | Abdi, R. M. (Adnoc Offshore, Abu Dhabi, United Arab Emirates) | Abdulla, M. F. (Adnoc Offshore, Abu Dhabi, United Arab Emirates) | Yakovlev, T. (Interwell Middle East, Abu Dhabi, United Arab Emirates) | Ross, S. (Interwell Middle East, Abu Dhabi, United Arab Emirates)
Abstract As wells completed with wireline retrievable downhole safety valves are becoming mature, issues related to seal bore and nipple profile tend to develop, causing the safety valve to be non-integral. Without a fully functioning downhole safety valve, these wells cannot produce and must be shut in. One option to overcome this issue is to utilize an Insert Valve Carrier (IVC) connected to the existing downhole safety valve (DHSV). The IVC has an anchoring mechanism to hang the system on depth, replacing the function of the damaged nipple. Also, it is equipped with upper and lower sealing elements to seal across the existing control line outlet in the tubing providing hydraulic fluid to operate the safety valve. An electronic setting tool sets the anchors at the pup joint slightly above the safety valve nipple while positioning the sealing elements across the control line outlet. The system is simple to use and can easily be set with Slickline, Electric Line, or Coiled Tubing with CCL capability for correlation or a No-go assembly. Several successful jobs were conducted between 2021-2022 in 4-1/2″ and 7″ completions in the Offshore Abu Dhabi field. Before mobilization, System Integrity Test is performed to ensure the system passes the pressure test and the safety valve functions properly. In this operation, the IVC and the safety valve were set using an Electric Line, taking advantage of real-time reading from the CCL for correlation. Once on depth, a signal was sent from the surface, setting the anchors and sealing elements. A normal procedure to apply pressure in the control line was performed. When the pressure holds, it provides a positive indication that the packing elements seal properly. An inflow test on the flapper was performed to confirm its integrity. Following the installation, flow tests were performed at different rates to ensure the system worked fine and evaluate the potential. This system has successfully restored the downhole safety valve functionality, which permits the wells to produce again after being inactive for a long time. In addition, the success of this system eliminates the need for expensive workovers.
Guan, Xu (Exploration and Development Research Institute of PetroChina Southwest Oil & Gasfield Company, Chengdu, China) | Zhu, Deyu (Exploration and Development Research Institute of PetroChina Southwest Oil & Gasfield Company, Chengdu, China) | Tang, Qingsong (PetroChina Southwest Oil & Gasfield Company, Chengdu, China) | Wang, Xiaojuan (Exploration and Development Research Institute of PetroChina Southwest Oil & Gasfield Company, Chengdu, China) | Wang, Haixia (Exploration and Development Research Institute of PetroChina Southwest Oil & Gasfield Company, Chengdu, China) | Zhang, Shaomin (Exploration and Development Research Institute of PetroChina Southwest Oil & Gasfield Company, Chengdu, China) | Deng, Qingyuan (Exploration and Development Research Institute of PetroChina Southwest Oil & Gasfield Company, Chengdu, China) | Yu, Peng (Exploration and Development Research Institute of PetroChina Southwest Oil & Gasfield Company, Chengdu, China) | Yu, Kai (Exploration and Development Research Institute of PetroChina Southwest Oil & Gasfield Company, Chengdu, China) | Huang, Xingning (Downhole service company of Xibu Drilling Engineering Company Limited, Karamay, China) | Xu, Hanbing (CNPC, International HK LTD Abu Dhabi, Abu Dhabi, UAE)
Abstract In recent years, tight sandstone gas as one of the important types of unconventional resources, has been rapid explored and developed. There are large-scale tight sandstone gas production in Sichuan Basin, Ordos Basin, Bohai Bay Basin, Songliao Basin and other basins, and it has become a key part in the area of increasing gas reserves and production in China. Due to the influence of the reservoir characteristics, tight gas reservoirs have low porosity and permeability, and the tight gas can only be effectively developed by improving the conductivity around the wellbore. Therefore, it is required to perform hydraulic fracturing after the completion of horizontal well drilling to improve the permeability of reservoir. It can be seen that hydraulic fracturing is the core technology for efficient development of tight gas resources. The implementation of hydraulic fracturing scheme directly determines the horizontal well production and EUR. This paper describes the workflow of 3D geomechanical modeling, technical application for Well YQ 3-3-H4 reservoir stimulation treatment, and carries out hydraulic fracture propagation simulation research based on 3D geomechanical model. This paper also compares the micro-seismic data with the simulation results, and the comparison results show that the propagation model is consistent with the micro-seismic monitoring data, which verifies the accuracy of the model. This paper clarifies the distribution law of hydraulic fractures in the three-dimensional space of horizontal wells in YQ 3 block, and the research results can be used to provide guidance and suggestions for the optimization of fracturing design of horizontal wells in tight gas of Sichuan Basin.
Zhu, Jun (Vertechs Energy Group) | Zhang, Wei (Vertechs Energy Group) | Zeng, Qijun (Vertechs Energy Group) | Liu, Zhenxing (Vertechs Energy Group) | Liu, Jiayi (PetroChina Southwest Oil & Gas Field Company) | Liu, Junchen (PetroChina Southwest Oil & Gas Field Company) | Zhang, Fengxia (PetroChina Southwest Oil & Gas Field Company) | He, Yu (PetroChina Southwest Oil & Gas Field Company) | Xia, Ruochen (PetroChina Southwest Oil & Gas Field Company)
Abstract In the past decade, the operators and service companies are seeking an integration solution which combines engineering and geology. Since our drilling wells are becoming much more challenging than ever before, it requires the office engineer not only understanding well construction knowledge but also need learn more about geology to help them address the unexpected scenarios may happen to the wells. Then a novel solution should be provided to help engineers understanding their wells better and easier in engineering and geology aspects. The digital twin technology is used to generate a suppositional subsurface world which contains downhole schematic and nearby formation characteristics. This world is described in 3D modelling engineers could read all the information they need after dealt with a unique algorithm engine. In this digital twin subsurface world, the engineering information like well trajectory, casing program, BHA (bottom hole assembly) status, are combined with geology data like formation lithology, layer distribution and coring samples. Both drilling or completion engineers and geologist could get an intuitive awareness of current downhole scenarios and discuss in a more efficient way. The system has been deployed in a major operator in China this year and received lot of valuable feedback from end user. First of all, the system brings solid benefits to operator's supervisors and engineers to help them relate the engineering challenges with according geology information, in this way the judgement and decision are made more reliable and efficiently, also the solution or proposal could be provided more targeted and available. Beyond, the geology information from nearby wells in digital twin modelling could also provide an intuitional navigation or guidance to under-constructed wells avoid any possible tough layers via adjusting drilling parameters. This digital twin system breaks the barrier between well construction engineers and geologists, revealing a fictive downhole world which is based on the knowledge and insight of our industry, providing the engineers necessary information to support their judgement and assumption at very first time when they meet downhole problems. For example, drilling engineers would pay extra attention to control the ROP (rate of penetration) while drilling ahead to fault layer at the first time it is displayed in digital twin system, which prevent potential downhole accident and avoid related NPT (non-production time). The integration of engineering and geology is a must-do task for operators and service companies to improve their performance and reduce downhole risks. Also, it provides an interdisciplinary information to end user for their better awareness and understanding of their downhole asset. Not only help to avoid some possible downhole risks but also benefit on preventing damage reservoir by optimizing the well construction parameters.
Ekpe, J. (KOC Kuwait Oil Company) | Al-Shehab, A. Y. (KOC Kuwait Oil Company) | Al-Othman, A. (KOC Kuwait Oil Company) | Baijal, S. (KOC Kuwait Oil Company) | Nguyen, K. L. (KOC Kuwait Oil Company) | Al-Morakhi, R. (KOC Kuwait Oil Company) | Dasma, M. (KOC Kuwait Oil Company) | Al-Mutairi, N. (KOC Kuwait Oil Company) | Verma, N. (KOC Kuwait Oil Company) | Quttainah, R. B. (KOC Kuwait Oil Company) | Janem, M. (Reservoir Group/Corpro) | Deutrich, T. (CORSYDE International) | Wunsch, D. (CORSYDE International) | Rothenwänder, T. (CORSYDE International) | Anders, E. (CORSYDE International) | Mukherjee, P. (MEOFS Middle East Oilfield Services)
Abstract The successful recovery of pressurized core samples from an unconventional HPHT reservoir is presented. Optimized methods and technologies such as implementation of Managed Pressure Drilling (MPD) technique as well as coring technology customization and adaptation are discussed. Results from offset wells are compared and a best practice method is described how to recover pressurized cores from the organic rich Najmah Kerogen in West Kuwait. A coring BHA was configured using a modified version of the LPC Core Barrel hence allowing for the first time to consider recovering pressurized core samples from a well with a very challenging operating envelope. Furthermore, the provided methodology ensures that well conditions are maintained to allow for a pressurized core recovery in most stable wellbore environment avoiding any unwanted subsurface problems. With three consecutive runs planned on for the pressurized coring using MPD each 10 ft., the results obtained showed a successful coring operation of which typical wellbore downhole issues were avoided with no loss time due to well ballooning, mud losses and well kicks. The successful coring operations as well as all subsequent on-site analysis procedures showed possibility to recover pressurized core samples from unconventional formations with high formation pressure in a safe and effective manner. Avoiding core damage due to petal-centerline fractures and disking is fundamental in quantifying natural fractures in this unconventional reservoir. This novelty approach of core barrel system modification and using MPD technique in acquiring the pressurized cores has made it possible to obtain representative near in-situ data to better reservoir interpretation and quantification of natural fractures. The method has a great potential to ensure high core recovery in high angle wells while delivering superior reservoir fluid and rock information which is not obtainable by other means.
Di, J. (CNPC Offshore Engineering Co Ltd) | Zhao, X. (PetroChina Investment Overseas Middle East Limited-Abu Dhabi) | Lv, J. (CNPC Offshore Engineering Co Ltd) | Rao, L. (PetroChina Investment Overseas Middle East Limited-Abu Dhabi)
Abstract For matured offshore oil field in Abu Dhabi, lots of wells need to be permanent abandonment. According to the regulations on offshore permanent well abandonment, the wellhead shall be cut from 4 m below the mudline. The purpose of this paper is to introduce an abrasive waterjet technology to solve the challenge so that cut two or three casings around seabed which is cemented together with a high efficiency method. Traditional operations for cutting multi-casing depend on milling cement and cutting single layer, which are inefficiency and time cost. Abrasive Waterjet technique utilize high water with abrasive material to cut multi-layer casing. This method does not limited to casing layer mount and size. The abrasive waterjet system is mainly composed of speed rotation control system, hydraulic anchoring system, cutting tools, ground supporting equipment, etc. The nozzle parameters were optimized by flow field simulation, and the corresponding tools were designed. The cutting tools includes several spray nozzles and transmit high pressure abrasive to casing surface to cutting. The cutting tools 360 degree rotation powered by speed rotation control system and fixed by hydraulic anchoring system. The abrasive waterjet is placed in cutting location in inner casing. A two-caisng cementing inner casing 339.7mm and outer casing 850mm together is used as an experimental target. In order to closer simulate the actual working conditions on site, inner casing has 150mm off-center. The abrasive waterjet was inside the target to cutting. The system connects to a pump with 70MPa and 0.9-1.0m/min flow rate. 40-60 mesh garnet is used as abrasive material. In order to simulate the cutting conditions on offshore site, the cutting tool is always submerged under the water during the test. After about 8 hours of experiments, the target cutting is successfully completed, and the cutting head and protective sleeve, hydraulic rotation speed control device and hydraulic anchoring device work smoothly, which proves that the abrasive jet cutting system has reasonable design and stable performance. The wear resistance of the nozzle during the experiment is analyzed. The nozzle does not change in the outlet diameter after 8 hours wear. Through this experimental research, it is proved that the reasonable selection of nozzle parameters and construction parameters can meet the overall cutting of eccentric multi-layer casing. This parameters can support for on-site construction parameter selection. If a traditional milling method to solve this problem, it usually takes several days. The advantages of this technology in time efficiency are proved. In addition, an offshore abandonment operation was applied by this technique which was conducted on a three-casing cemented casing. This paper will provide a novel method to solve the multi-casing cutting challenge for offshore well permanent abandonment. The abrasive jet cutting system design, tools and parameters feasibility of field application are verified. Compare to traditional method, it can greatly reduce the operation time and project cost.
Huang, Yi (CNOOC China Limited, Zhanjiang Branch, Zhanjiang 524057, China) | Liu, Hexing (CNOOC China Limited, Zhanjiang Branch, Zhanjiang 524057, China) | Liu, Zhiqin (CNOOC China Limited, Zhanjiang Branch, Zhanjiang 524057, China)
Abstract L2 formation of X Oilfield in western South China Sea is of characteristic of low porosity, low permeability and well controlled reserves, and long well interval, drainage area and controlled reserves can be significantly increased by adopting ultra-short radial radius drilling technology. Flexible drill pipe and drill bit was used in Well WZ-X1 to perform kick-off operation with only 2.4 m footage to increase inclination from 37 °to 87 °, and hold its inclination by drilling 60-62 m alongside reservoir with trajectory control margin of ±2°. This paper highlights the trajectory control technology with research of BHA, build-up and hold drill bit, and accurate calculation. During the field operation, drilling parameters were adjusted on the basis of formation variation and outstanding trajectory effect was accomplished and ultra-short radial radius trajectory control technology was achieved. This technology can solve the problem of trajectory control and extend horizontal section of reservoir. It can increase wellbore drainage area and well control reserves, providing technical reference for future operation.
Wu, Bohong (Research Institute of Petroleum Exploration & Development, PetroChina, Beijing, China) | Qiu, Ping (China University of Petroleum, Beijing, China) | Shi, Shuzhe (Research Institute of Petroleum Exploration & Development, PetroChina, Beijing, China) | Zhang, Yanna (Research Institute of Petroleum Exploration & Development, PetroChina, Beijing, China) | Huang, Xueqin (Research Institute of Petroleum Exploration & Development, PetroChina, Beijing, China) | Nie, Zhen (Research Institute of Petroleum Exploration & Development, PetroChina, Beijing, China)
Abstract In a Middle East oilfield, reservoirs are characterized by high temperature, high salinity, high CO2 / H2S content, and low pH, which leads to harsh corrosive environment. With development of the field, the increasing water cut and application of CO2-EOR technology have made tubulars face greater corrosion risk. Therefore, employing feasible anti-corrosion coating to corresponding part is one of the most effective technologies to mitigate downhole corrosion risk, reduce workover, and avoid potential HSE risk. Corrosion environment characteristics was thoroughly studied by reviewing production history, water chemistry, gas composition, downhole temperature and pressure, logging data, etc. Downhole corrosion condition was classified based on NACE standard RP0775-2005. Based on this, the field simulated corrosion tests were carried out on the self-healing coating in high-temperature and pressure autoclave. The self-healing coating was fabricated by loading slow-released MBT-LDH nanocomposites to the phenolic epoxy resin. For comparison, the similar experiment was also conducted on commercial phenolic epoxy coating and heavy-duty coating. The anti-corrosion performance and applicability of the coatings were characterized by SEM/EDS, FT-IR and EIS. Two main factors have been considered while evaluating the coating options, the first consideration is reliability and durability of the coating. If the coating is easily damaged during operation and transportation, its protective performance decreases after damage, which cannot be easily repaired again. The second consideration is the compatibility of the coating in a harsh downhole environment. Considering the above aspects, the self-healing coating, commercial phenolic epoxy coating and commercial heavy-duty were selected. After corrosion tests, a small amount of corrosion products can be observed on the commercial phenolic epoxy coating surface both in the simulated well head and bottom condition. There were no obvious morphology changes on the heavy-duty coating surface in both condition, however, chemical degradation of the coating was observed in well bottom condition. Notably, the self-healing coating appeared no peeling, bubbling and other defects in both conditions. There were corrosion products identified in the pre-destructed area of the coating, which attributed to the localized inhibition of the self-healing coating. This paper investigated the corrosion resistance coating technology, including coating selection evaluation, typical tubing thread area protection technique, coating chemical and physical property analysis and evaluation. The study also recommended coating applicability for the target reservoir. The results suggested that phenolic epoxy based self-healing coating show robust anti-corrosion performance and can be used in the downhole containing CO2 and H2S.
Abstract Scarcity of water resources in UAE and affording a nonstop water supply for drilling operation was always a concern. The main objective of availing a fit for purpose solution was: Saving the underground water resources. Cost optimization: Saving the cost of Haulage transportation. (30-50%) Save the Total Value of waste disposal injection package. Saving the cost of salt as the treatment technologies is designed to save the salt content. HSE advantage by reducing the Transportation requirements. Simple to implement in all ADNOC rigs fleet Not affect the rig operation. Dewatering of the waste drilling fluid It is the most common and promising treatment technology. Dewatering It is the most common and promising drilling fluids waste treatment technology, this technology depends on 2 simple Mechanisms which is Coagulation and Flocculation (chemical treatment) –Coagulation is the water treatment process that causes very small, suspended particles to attract one another and form larger particles. –Flocculation is the water treatment process where the coagulated particles (pinpoint flocs) bridge together resulting in larger, more shear resistant structures that settle faster with less carryover of solid particles into the separated water.