Day 2 Wed, March 23, 2022最新文献

{"title":"A Successful Case Study of a Collaborative Approach in Operational Optimization via Adoption of Automated Drilling Performance Measurement","authors":"Muhammad Afiq Arif Normin, Azlesham Rosli, M. M. H. Meor Hashim, M. Arriffin, Rohaizat Ghazali","doi":"10.4043/31579-ms","DOIUrl":"https://doi.org/10.4043/31579-ms","url":null,"abstract":"\u0000 Digital transformation has always been one of the focuses of the oil & gas industry players in recent years. However, the pandemic and oil downturn last year has put the industry players in a digitization overdrive in the pursuit of leaner and cost-effective operations to stay ahead in these unprecedented times. This paper discusses the strategy, approach, and challenges in the adoption and implementation of the Automated Drilling Performance Measurement (ADPM) onsite and remote approach. This includes Wells Real-Time Center (WRTC), which utilizes the ADPM, an easy access analysis application for operational optimization. The implementation of ADPM falls under the PETRONAS Well Cost Compression focus area of Operational Optimization, which aims to achieve the operational technical limit and non-productive time (NPT) reduction. The stages of operational optimization via ADPM are broken down into pre-spud operations, operations, and post-well analysis. A historical performance study is conducted in pre-spud operations and case study sessions with the project team and Subject Matter Experts (SMEs). Once in operations, best practices for the focused key performance indicator (KPI) and ad-hoc gap analysis are implemented onsite throughout the well construction. Remotely, the KPIs are monitored by WRTC while rig contractors monitor the crew performance. The performance review is studied in post-well analysis, and the best practices are compiled for replication and lesson learned to improve future well's excellence. The evaluation of rig performance is conducted based on the focused KPIs criteria and Rig Scorecard criteria. Implementation of ADPM set clear and defined strategy from top management on digitalization and performance optimization. ADPM also helps foster performance optimization awareness and culture with clearly defined roles, responsibilities, and expectations. For example, the application deployment for the Field B drilling campaign focused on tripping, drilling and casing KPI improvement while utilizing ADPM for data gathering and analysis. The result of this deployment is commendable, with a total actual savings of 2.94 days gained throughout the campaign. From 2016 to 2021, PETRONAS has gained a total of 39.03 days of actual savings for their entire rig fleet.","PeriodicalId":11081,"journal":{"name":"Day 2 Wed, March 23, 2022","volume":"30 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"75269123","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Pseudocode and Demonstration of a Multi-Use Artificial Intelligence Algorithm to Perform Challenging and Highly Optimised Pipeline/Cable Routing Cases","authors":"N. Lim, L. Lim, Haribabu Komatineni","doi":"10.4043/31360-ms","DOIUrl":"https://doi.org/10.4043/31360-ms","url":null,"abstract":"\u0000 The process of routing energy conduits (pipelines, cables and umbilicals) in offshore locations represents a critical phase in the concept planning, engineering and construction of these assets. The downstream impact of poorly designed routes is epitomized by a) increased offshore construction durations b) requirements for additional engineered mitigations from geophysical / geotechnical constraints and c) unforeseen requirements for intervention during operations. The cause of these unoptimized routes can be due to low-level engineering tasks which confines to repetitive, inefficient, and unnecessarily iterative processes between draughters, engineers and asset owners. The increasing accessibility and advancement of digital technologies enables highly optimised solutions even through difficult offshore regions.\u0000 To address the above, this paper presents the scoping, development and application of a multi-functional algorithm created using modern software code frameworks. The algorithm serves as building blocks into an artificial intelligence platform. This routing algorithm simulates, expands and adapts to engineering and consulting expertise from a worldwide network of energy experts. This recreation of expertise firstly identifies commonly encountered routing constraints such as geophysical features, seabed gradients, existing offshore facilities etc. Ideal geometric parameters are then determined to minimise route costs. These processes are then increased, thus enhancing expertise through scale.\u0000 The algorithm structure will be presented in summarised minimal pseudocode. The pseudocode will present the application programming interface (API) between the constraints based and end parameter calculation approach. The API includes digital innovations such as a) processing of offshore geotechnical survey data, b) recreating offshore locales and routes in a data environment, c) implementation of geospatial intersection detection, d) 3-dimensional route length optimisation and e) automated route selection criteria. This will demonstrate the order of magnitude replication of subject matter expertise into a digital realm, thus eliminating time-consuming, repetition and human error.\u0000 Finally, the application of the algorithm will be demonstrated by various case studies of offshore locales with challenging conditions such as highly disturbed seabeds and large quantities of existing man-made assets. The front-end cloud platform of the algorithm will be exhibited, showing a streamlined approach and improved routing engineering. Through this, engineers in the future offshore energy developments can answer the question \"What is the best route?\".","PeriodicalId":11081,"journal":{"name":"Day 2 Wed, March 23, 2022","volume":"284 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"75625670","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"World'S First Successful Dual String Installation of A Digital Intelligent Artificial Lift DIAL – Interventionless Gas Lift Production Optimization System, Offshore Malaysia","authors":"M. Rozlan, M. H. M Ghazali, M. F. Bakar, M. F. Ishak, Orient Balbir Samuel, M. Misron, Mohamad Sazwan Ismall, N. I. Salleh, Badroel Rizwan, A. Amara, Stephen Faux, Ahmad Hafiz Ahmad Azhari, Azis Anak Muara","doi":"10.4043/31563-ms","DOIUrl":"https://doi.org/10.4043/31563-ms","url":null,"abstract":"\u0000 PETRONAS completed well H-X on B field in Malaysia with a Digital Intelligent Artificial Lift (DIAL) gas lift production optimization system. This DIAL installation represents the first ever successful installation of the technology in an Offshore well for Dual String production. This paper provides complete details of the installation planning and operational process undertaken to achieve this milestone.\u0000 DIAL is a unique technology that enhances the efficiency of gas lift production via downhole monitoring of production parameters informs remote surface-controlled adjustment of gas lift valves. This enables automation of production optimization removing the need for well intervention.\u0000 This paper focusses on a well completed in November 2020, the fourth well to be installed with the DIAL technology across PETRONAS Assets. The authors will provide details of the well and the installation phases: system design, pre-job preparations, improvements implementation, run in hole and surface hook-up. For each phase, challenges encountered, and lessons learned will be listed together with observed benefits.\u0000 The DIAL system introduces a paradigm shift in design, installation and operation of gas lifted wells. This paper will briefly highlight the justifications of this digital technology in comparison with conventional gas lift techniques. It will consider the value added from the design stage, through installation operations, to production optimization.\u0000 This successful installation confirms the ability to implement the DIAL technology in a challenging dual string completion design to enable deeper injection while avoiding interventions on a well with a greater than 60-degree deviation. With remotely operated, non-pressure dependent multi-valve in-well gas lift units, the technology removes the challenges normally associated with gas-injected production operation in a dual completion well – gas robbing and multi-pointing.\u0000 Despite the additional operational & planning complications due to COVID-19 restrictions, the well was completed with zero NPT and LTI. Once brought online, this DIAL-assisted production well will be remotely monitored and controlled ensuring continuous production optimization, part of PETRONAS' upstream digitization strategic vision.","PeriodicalId":11081,"journal":{"name":"Day 2 Wed, March 23, 2022","volume":"244 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"75755928","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Improving Aging Field Value Through Production Data Revitalization","authors":"I. Jamaludin, Zhaoyuan Tan, Nicholas Aloysius Surin, Zhong Ying Hew","doi":"10.4043/31524-ms","DOIUrl":"https://doi.org/10.4043/31524-ms","url":null,"abstract":"\u0000 Field-D consists of multi-stacked oil reservoirs with commingle production and dual strings. Well integrity issues are main challenges causing crossflow between zones and unintentional production/injection. With massive effort of rebuilding static model and rework on history matching (HM), many inconsistencies of production data allocation were discovered, such as oil recovery factor (RF) >60%. This paper discusses the exercise of cleaning up production data as per latest subsurface understanding and memory production logging tool (MPLT) campaigns.\u0000 Reinterpretation of stratigraphic correlation, depositional environment, and petrophysical parameters are among major workflows during the static model rebuilding process. As current reservoir allocations are based on legacy permeability-thickness (KH) ratio, the requirement to revise allocation split based on latest understanding is considered compulsory. This is further justified by dynamic modeling HM exercise where inconsistencies are observed between legacy data and model response, resulting in poor HM quality and unrealistic RF, suggesting different production/injection distribution than in current database. Additionally, MPLT campaign is executed every year to obtain latest split percentage. A pilot exercise is embarked on to redefine contribution for each zone in every well in fault block VIII and rerun allocation starting day 1.\u0000 Successful production data allocation rerun is expected to demonstrate representative RF for individual reservoir. Higher RF are expected for zones with secondary drive mechanism i.e., water and gas injection, as opposed to natural depletion reservoirs (NDR). This exercise also will enable accurate reporting during the Annual Reporting of Petroleum Resources (ARPR) to the host government. Additionally, more accurate forecast using decline curve analysis (DCA) can be realized, and robust analysis can be performed to improve respective reservoir RF. Better well management also is anticipated as zonal isolation such as water or gas shut off or adding perforation jobs can be properly planned and executed. Looking from injection well point of view, proper distribution will be possible so that only targeted zones will receive the pressure support. A full field implementation is currently ongoing for the rest of fault block in Field-D.","PeriodicalId":11081,"journal":{"name":"Day 2 Wed, March 23, 2022","volume":"42 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"77638566","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Hydraulic Fracturing to Investigate Impact of Fracturing Medium, Bedding Angle and Perforation Length on Fracture Growth in Low and High Brittle Shale","authors":"J. Khan, E. Padmanabhan, Izhar Ul-Haq","doi":"10.4043/31531-ms","DOIUrl":"https://doi.org/10.4043/31531-ms","url":null,"abstract":"\u0000 Advancements in the technique for early estimation of the hydraulic fracturing potential of fracturing fluid in different shale formations are needed to successfully stimulate reservoir volume and recover the trap hydrocarbons. The determination of fracture initiation and propagation in shale remains unclear, particularly with regard to the choice of type of fracturing fluid during fracturing operation at high confinement. Hydraulic fracturing with supercritical carbon dioxide (SC CO2) and SC CO2 foam are an encouraging technique to overcome significant use of water in shale gas production. Our study was carried out to explore the fracture propagation and fracture initiation pressure under high confinement stress. The hydraulic fracturing experiments are performed to study fracture propagation in the black shale of three different fields to generalize the scope of work using low, medium and high brittle shale: Eagle Ford, Wolfcamp and Mancos. Three different fracturing fluids were selected for fracturing tests: SC CO2, SC CO2 foam and slick water to investigate the impact of low, medium and high viscous fluids. We evaluated the fracture pressure curve, breakdown pressure (fracture initiation pressure), fracture network variation and the impact of bedding angle, perforation length, injection mediums and formation variations on fracture morphology. During hydraulic fracturing with slick water a consistent rise in the injection pressure is recorded whereas sudden fluctuations are recoded with the injection of SC CO2. With the injection of SC CO2 foam, a sudden decrease in injection pressure appears due to imbibition of SC CO2 foam in the pores matrix. Moreover, fracture initiation pressures in shale rocks varied by changing bedding angle and perforation length. Fracture initiation pressure increases with bedding angles. An appreciable difference in fracture initiation pressure with SC CO2, SC CO2 foam and slick water are 5023psi, 6456psi and 6168psi, respectively at high conferment pressure (3500psi). Comparison of hydraulic fracturing of Eagle Ford, Wolfcamp and Mancos shale with different injection medium shows that SC CO2 foam produced complex fracture networks with high aperture and length for parallel, inclined and perpendicular perforations along the bedding. With all types of shale, SC CO2 foam injection has produced dense fracture network. Thus, fracturing with SC CO2 foam can potentially enhance the stimulated reservoir volume.","PeriodicalId":11081,"journal":{"name":"Day 2 Wed, March 23, 2022","volume":"57 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"77034177","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Qualification of Cost Effective Mechanically Lined Pipe Solutions for Reel-Lay Installation","authors":"R. Jones, G. Toguyeni, Radzlan Ahmad Suhaimi, J. Banse","doi":"10.4043/31362-ms","DOIUrl":"https://doi.org/10.4043/31362-ms","url":null,"abstract":"\u0000 The use of mechanically lined pipe (MLP) for both flowlines and risers installed by reel-lay is well established, giving significant cost and schedule benefits relative to conventional metallurgically clad pipe. Successful offshore installation of MLP is underpinned by comprehensive qualification testing. Evolving MLP products, including the use of thin liners and adhesively bonded MLP, i.e. GluBi®, continue to improve the competitiveness of this linepipe product. The paper will highlight the key steps for qualification, including new products, the lessons learnt captured during fabrication and installation as well as the benefit of a local spool base for the Asia Pacific region.\u0000 Subsea 7 has worked in close collaboration with leading supplier Butting to perform the qualification of MLP. The latter, initially, comprises extensive non-destructive and destructive testing of the linepipe materials including the liner/ weld overlay interface. Subsequently reeling test strings are fabricated using qualified welding solutions. Internal visual inspection and dimensional measurements are carried out using laser metrology to provide a benchmark for comparison post reeling. The test strings are given a simulated reeling procedure using bending and straightening formers, representative of Subsea 7's installation vessels. The internal pressurisation technique, as per standard installation practice for MLP, is applied during the simulated reeling procedure. The need for internal pressurisation is eliminated in the case of adhesively bonded MLP. Post reeling the internal laser metrology inspection procedure is repeated to confirm the integrity of the liner and to check for the presence of any evidence of liner wrinkling or damage. Subsequently, for riser applications, full-scale fatigue testing is performed using the high- frequency resonance bending procedure with a focus on the integrity of the junction between liner and weld overlay or, as commonly termed, the triple point.\u0000 Additionally, finite element analysis (FEA) is often performed to further validate the satisfactory reeling performance of the MLP. All the qualification activities are carried out and verified in alignment with DNV-RP-A203 Technology Qualification (Ref.1)\u0000 To date Subsea 7 has installed several hundreds of kilometers of MLP flowlines and risers, with pipe NPS in the range 7\" to 14\" and including 316L, Alloy 825 and Alloy 625 liners. This thorough qualification process and experience combined with the successful set up of a regional spool base provides a robust and cost-effective alternative to the conventional metallurgically clad pipe.","PeriodicalId":11081,"journal":{"name":"Day 2 Wed, March 23, 2022","volume":"67 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"79538822","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Leveraging Factor Analysis Machine Learning Workflow Concurrent with Advanced Volumetric Analysis to Improve Porosity-Permeability Transform in Complex Carbonate Reservoir","authors":"Muhamad Saiful Hakimi Daud, Sok Foon Lee, F. K. Wong, A. A. Yaakob, W. Tolioe, H. Harun, Ahmad Syahir Ahmad Fuad","doi":"10.4043/31513-ms","DOIUrl":"https://doi.org/10.4043/31513-ms","url":null,"abstract":"\u0000 Permeability determination is critical in understanding the viability of a project as it is often used as an economic indicator in the infill well placement, production strategy and enhanced oil recovery strategies. Often, well tests are planned, and core analysis are performed to evaluate the flow capability of the reservoir, but it may not be sufficient for heterogenous and complex carbonate formation. Hence, to determine the permeability, we often employ correlations such as resistivity-permeability relationship, intrinsic permeability estimation from geochemical data and most common and widely used is the porosity-permeability (poro-perm) relationship. Poro-perm relationship relies on the basis that all pores contribute to fluid flow. However, any heterogeneity, such as presence of isolated pores could cause this poro-perm relationship to fail. Hence, this paper aims to address the challenges associated with the quantification of the isolated pores in the formation.\u0000 The case study gas well, Well M, is in offshore of Sarawak, Malaysia. The nuclear magnetic resonance (NMR) logs are acquired to quantify porosity and permeability in addition to basic quad-combo and wireline formation tester (WFT) sampling. The direct porosity-permeability transform obtained from NMR Timur-Coates equation shows distinct disagreement by a factor of up to 100 with the mobility obtained from WFT. This discrepancy could be due to the incorrect assumption that all pores are interconnected, but in reality, some of the pores might be isolated porosity.\u0000 To unravel this complex problem, an advanced analysis incorporating the quad-combo data and NMR data is carried out in the volumetric solver. Since sonic is generally less sensitive to spherical pores, deviation seen between sonic porosity and total porosity is interpreted as the presence of spherical pore. After analyzing the core, it was found that these spherical pores are isolated in nature, hence sonic could be used as a quantification of isolated pores inside the formation. In addition, an unsupervised machine learning algorithm, NMR factor analysis (NMR FA) was performed on the NMR T2 Distribution to fully characterize the formation by analyzing the fluid residing in the pores. This was done via concurrent analysis of the NMR signal modelling. By leveraging machine learning of the NMR data, many of the critical information that would otherwise go undetected were extracted successfully.\u0000 Lastly, the factor analysis result was blindly compared to advanced volumetric analysis, and both methodologies yield the approximate the same volumes of isolated porosity in the formation of interest (R2 = 0.886). After the quantification of the isolated pores were successfully carried out and confirmed, a reliable poro-perm transform was established.\u0000 To conclude, poro-perm estimate in this field was enhanced and the permeability uncertainty is greatly reduced. Subsequently, the result from this workflow can be used as a quick ","PeriodicalId":11081,"journal":{"name":"Day 2 Wed, March 23, 2022","volume":"75 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"86299822","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Use of Oxygen Scavenger in Well Safety Valve Balancing Operations","authors":"M. Lehmann, K. Lepkova, T. Pojtanabuntoeng, Varun Ghodkay, Annamaria Greenwood, Susumu Hirano, Toshiyuki Sunaba","doi":"10.4043/31509-ms","DOIUrl":"https://doi.org/10.4043/31509-ms","url":null,"abstract":"\u0000 Monoethylene glycol (MEG) is often used to reduce the differential pressure across well valves so that they can be opened without damage. This MEG ultimately commingles with production fluids and if not deoxygenated contributes to the overall content of dissolved oxygen that may be seen by a receiving production facility. Normally, the dissolved oxygen levels would be removed to insignificant levels during fluid transport. Since the corrosion reactions sequester the oxygen as the fluids are exposed to less noble materials of construction, such as carbon steel. However, in facilities that utilise corrosion resistant alloys (CRA) the residual dissolved oxygen level can be so significant that it warrants reduction using oxygen scavengers. This paper reports on corrosion studies that illustrate the consequence of dissolved oxygen levels being carried through to a MEG reclamation unit constructed of CRA, and laboratory and field validation studies on the use of a bisulfite-based scavenger for removal of oxygen in 90wt% MEG used for equalising pressure of Subsurface Safety Valves.","PeriodicalId":11081,"journal":{"name":"Day 2 Wed, March 23, 2022","volume":"1 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"88873257","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"A Comprehensive Approach in Managing the Aftermath of Non-Conformance Seam Welded Linepipes","authors":"M. Aziz, M. A. DeSa, A. Jaafar, Hayati Hussien","doi":"10.4043/31671-ms","DOIUrl":"https://doi.org/10.4043/31671-ms","url":null,"abstract":"\u0000 PETRONAS had been notified by its pipe mill that some of the linepipe supplied by the mill were found to be non-compliance with agreed manufacturing process specification (MPS) and inspection & test plan (ITP). The non-conformances happened during longitudinal weld seam repair at the manufacturing stage. The notification has put PETRONAS on high alert as the affected linepipes have already been installed and commissioned as part of gas pipelines i.e. Pipeline 1 and Pipeline 2 supplying to onshore customer. This paper will discuss the investigation strategies implemented by PETRONAS' investigation team which include 1) multidisciplined investigation team, 2) Technical Safety Review, 3) Desktop Review and 4) Repair Simulation and Material Verification Testing. The paper also details out the type of non-conformance and associated hazards with corresponding action plan to address them. Engineering Criticality Assessment (ECA) was one of the critical processes in the investigation where simulated longitudinal weld samples from the linepipe underwent Crack Tip Opening Displacement (CTOD) test. The test provided fracture toughness value of the weld sample and became the main input in the ECA study. The objective of the ECA is to provide defect/ crack acceptance criteria based on methodology specified by BS7910. During ECA, the respective weld sample was analyzed against pipeline operating parameters coupled with fatigue stress mainly contributed by pressure variations. Crack growth was studied and compared against defect/ crack critical dimensions i.e. height, and length. Given all the investigations carried out combined with ECA experts review, the pipelines were proven safe and reliable to operate. The investigation outcomes have saved PETRONAS commercially while maintaining good safety record.","PeriodicalId":11081,"journal":{"name":"Day 2 Wed, March 23, 2022","volume":"18 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"83138271","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Successful Drilling of the Deepest and Hottest HPHT Carbonate Well in Central Luconia, Off the Coast of Sarawak, Offshore Malaysia","authors":"Swee Hong Gary Ong, Warapong Dejdamrongpreecha, Pawan Sookparkkit, Ungku Syafena Ungku Hamzah, Boon Shin Chia, Rurizalakmal Udin, Marzuki Zulkarnain, J. Manson, Chevit Phasook, L. Umar, N. Kongpat","doi":"10.4043/31574-ms","DOIUrl":"https://doi.org/10.4043/31574-ms","url":null,"abstract":"\u0000 HPHT wells are typically associated with high complexity, technically challenging, long duration, high risk and high NPT as many things could go wrong especially when any of the critical nitty- gritty details are overlooked. The complexity is amplified with high risk of losses in carbonate reservoir with high level of contaminants compounded by the requirement of high mud weight above 17 ppg during monsoon season in an offshore environment.\u0000 The above sums up the challenges an operator had to manage in a groundbreaking HPHT carbonate appraisal well which had successfully pushed the historical envelope of such well category in Central Luconia area, off the coast of Sarawak where one of the new records of the deepest and hottest carbonate HPHT well had been created.\u0000 This well took almost 4 months to drill with production testing carried out in a safe and efficient manner whereby more than 4000m of vertical interval was covered by 6 hole sections.\u0000 With the seamless support from host authority, JV partners and all contractors, the well was successfully delivered within the planned duration and cost, despite the extreme challenges brought about by the COVID-19 pandemic.\u0000 This paper will share the experience of the entire cycle from pre job engineering/planning, execution and key lesson learnt for future exploitations.","PeriodicalId":11081,"journal":{"name":"Day 2 Wed, March 23, 2022","volume":"48 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"90804597","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}