Sabah
Petronas Carigali has entered into a farm-out agreement (FOA) with SMJ Sdn Bhd (SMJSB), a company wholly-owned by the Sabah State Government for the sale of Petronas Carigali's 50% of nonoperating participating interest in the Samarang Production-Sharing Contract (PSC). Last month, Petronas Carigali and SMJSB inked a Heads of Agreement to record the parties' agreement and confirm SMJSB's participation in the Samarang PSC; this is superseded with the execution of the FOA. The FOA marks the second significant development between Petronas Carigali and SMJSB following the Commercial Collaboration Agreement signed between Petronas and the Sabah State Government on 7 December 2021. Under the FOA, Petronas Carigali will continue to be the operator of Samarang PSC with SMJSB on board as the nonoperating partner. The Samarang field, which is located 50 km off the coast of Sabah is currently producing approximately 36,000 BOED.
- Government > Regional Government > Asia Government > Malaysia Government (1.00)
- Energy > Oil & Gas > Upstream (1.00)
Abstract Block H, located in 1,300 meters of water depth at offshore Sabah, consists of Rotan and Buluh fields. The subsea trees, jumpers, manifold, umbilicals, risers and flowlines were installed and tied-back to an FLNG facility. The objective of this project was to develop most practical and effective solutions to overcome flow assurance challenges owing to low seabed temperature and high-pressure gas to achieve 1 gas from the first deepwater gas field in Malaysia. A model was built in OLGA software with all field conditions to run simulations and predict process parameters at every critical point in subsea wells, risers and flowlines as well as topside facilities. Besides, all constraints from the subsea wells, jumpers, risers and flowlines all the way to topside inlet receiving facilities were carefully reviewed and optimized with an abundance of caution to determine the stepwise approach by utilizing the high-pressure gas from wells to remove around 1,000 m of pre-filled MEG fluid out of the flowline, called โDeMEG operationโ before feeding gas to LNG process operations. With 200-230 barg pressures from deepwater gas wells and 2-4ยฐC temperature at seabed as well as pre-existing water content in saturated gas given by reservoir aquifer, this start-up operation would expect to be in the hydrate zone. One of the unavoidable potential consequences was a hydrate formation and could result in plugging of jumpers, risers or even flowlines. The DeMEG operation results indicated the lowest temperature at the downstream of the subsea choke was โ23ยฐC due to Joule-Thompson cooling during the cold start. One mitigation strategy was to inject a batch of MeOH at the subsea wellhead until the temperature is above the hydrate point. After the gas flowed along the flowlines, it would cool down to the seabed temperature during the steady state condition. Hence, additional mitigation was to continuously inject Mono Ethylene Glycol (MEG) as another thermodynamic hydrate inhibitor mixed with gas stream. The MEG affixed water molecules and thus deterred them from forming a cage around gas molecules to prevent hydrate formation. A multi-stage DeMEG operation was carefully planned to overcome liquid handling capacity at topside and eventually executed at offshore until the remaining MEG in the flowline was as low as reasonably practical to proceed with gas production from the field. With an excellent collaboration from the team and proper planning, the DeMEG solution together with hydrate mitigation strategy were proven to be effective and the commissioning operation was successfully completed as per the plan until the 1 gas was achieved on 6-Feb-21 and supplied to FLNG. The 1 LNG drop subsequently came in 7 days later. This field has increased production volume around 270MMSCFD, equivalent to 45,000 barrels of oil per day to PTTEP and JV partners.
- Asia > Thailand (0.92)
- Asia > Malaysia > Sabah > South China Sea (0.25)
- Energy > Oil & Gas > Upstream (1.00)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (0.68)
- Government > Regional Government > Asia Government > Thailand Government (0.52)
- Asia > Indonesia > Java > Central Java > Blora Regency > Asset 4 Area > Trembul Block > Trembul Field > Ngrayong Formation > P1 Well (0.99)
- Asia > Malaysia > Sabah > South China Sea > Sabah Basin > Block H > Rotan Field (0.94)
- Asia > Malaysia > Sabah > South China Sea > Sabah Basin > Block H > Buluh Field (0.94)
Expanding the Envelopes of Openhole Gravel Packing in Sabah Deepwater Malaysia
Nopsiri, Noppanan (PTTEP Sarawak Oil LTD) | Samuel, Elvy (PTTEP Sarawak Oil LTD) | Chan Fong, Lee (PTTEP Sarawak Oil LTD) | Kalalo, Alxner (Pertamina Malaysia EP) | Moses, Nicholas (Schlumberger Malaysia) | Jayadi, Agus (Schlumberger Malaysia) | Yi, Ding (Schlumberger Malaysia)
Abstract Amongst the challenges encountered during infill drilling and completion is the requirement to penetrate depleted zones drained during the early phases of the field development. This condition is exacerbated for completions requiring openhole gravel pack as the maximum openhole lengths are traditionally limited by the effective circulating density experienced during the openhole drilling and gravel packing. This paper discusses the techniques implemented in four openhole gravel pack completions with openhole lengths up to 858m marking a new record for the longest openhole completed by PTTEP in this field. The wells were deployed by PTTEP in the Malaysian Deepwater Block K, during the field development of Siakap North Petai Phase 2, executed between Q4 2021 and Q1 2022.
- North America > United States (1.00)
- Asia > Malaysia > Sabah > South China Sea (0.48)
- Europe > United Kingdom > North Sea > Northern North Sea > East Shetland Basin > P 1575 > Block 9/2c > Kraken Field > Heimdal Formation (0.99)
- Europe > United Kingdom > North Sea > Northern North Sea > East Shetland Basin > P 1575 > Block 9/2b > Kraken Field > Heimdal Formation (0.99)
- Asia > Malaysia > Sabah > South China Sea > Sabah Basin > Block K > Siakap North and Petai Fields (0.99)
- (6 more...)
- Well Drilling > Drilling Operations (1.00)
- Well Completion > Sand Control > Gravel pack design & evaluation (1.00)
Advancement of Open Hole Gravel Pack and Zonal Isolation with Selective Intelligent Completion in Deepwater Malaysia
Samuel, Elvy (PTTEP Sarawak Oil LTD) | Nopsiri, Noppanan (PTTEP Sarawak Oil LTD) | Chan Fong, Lee (PTTEP Sarawak Oil LTD) | Kalalo, Alxner (Pertamina Malaysia EP) | Moses, Nicholas (Schlumberger Malaysia) | Jayadi, Agus (Schlumberger Malaysia) | Yi, Ding (Schlumberger Malaysia) | Nordin, Amirul (Schlumberger Malaysia) | Teoh, Melissa (Schlumberger Malaysia)
Abstract As fields mature, the drilling and completion design and execution for infill development becomes challenging. In a deepwater environment, one of the strategies to address this challenge is to optimize subsea facilities by targeting several reservoir packages in a single wellbore. However, this technique comes with technical challenges because penetrating different zones requires active reservoir management, an allowance for zonal isolation, and an adequate response to potential crossflow. A smart completion architecture should overcome these constraints and reduce overall capital expenditure while maximizing production. Furthermore, for wells requiring sand control, the completion solution must ensure a reliable and proven approach that minimizes the potential completion failures introduced by unsuccessful sand retention. This paper presents the completion strategy implemented in an intelligent well completed in the Malaysian deepwater Block K, during the field development of Siakap North Petai (SNP) Phase 2 and executed in Q1 2022.
- North America > United States (1.00)
- Asia > Malaysia > Sabah > South China Sea (0.34)
- Europe > United Kingdom > North Sea > Northern North Sea > East Shetland Basin > P 1575 > Block 9/2c > Kraken Field > Heimdal Formation (0.99)
- Europe > United Kingdom > North Sea > Northern North Sea > East Shetland Basin > P 1575 > Block 9/2b > Kraken Field > Heimdal Formation (0.99)
- Asia > Malaysia > Sabah > South China Sea > Sabah Basin > Block K > Siakap North and Petai Fields (0.99)
- (5 more...)
- Well Drilling > Pressure Management > Well control (1.00)
- Well Drilling > Drillstring Design (1.00)
- Well Drilling > Drilling Operations (1.00)
- (12 more...)
Application of Key Deepwater Lessons Learned in Marginal Deepwater Development, Offshore Malaysia
Khalid, Aizuddin (PETRONAS Carigali Sdn Bhd) | Hamza, Norashikin (PETRONAS Carigali Sdn Bhd) | A Rahim, Mas Rizal (PETRONAS) | A Rahman, Amir Ridzwan (PETRONAS Carigali Sdn Bhd) | Patma Nesan, Thanavathy (PETRONAS Carigali Sdn Bhd) | M Sahid, Norhayati (PETRONAS Carigali Sdn Bhd)
Abstract L & B fields offshore Sabah, Malaysia will be the next deepwater development in Malaysia after Kikeh, Siakap North-Petai, Gumusut-Kakap & Malikai. However, in comparison, L & B are considered marginal in terms of recoverable volumes and size of project, making it crucial to design and execute the project sharply to ensure value delivery. 5 key deepwater lessons learned areas are discussed in this paper as applied to L & B Field Development Plan (FDP) to ensure technical robustness based on experience of surrounding deepwater fields. The first key area is subsea production stability and flow assurance. Among critical evaluations conducted were techno-commercial comparison of dual-loop pipe-in-pipe against heated pipe-in-pipe, upfront artificial lift plans, and water injectors design to avoid hydrates formation as observed in another field. The second critical area is in drilling where key lessons were to conduct thorough geohazard analysis for hazard identification and avoid wellhead subsidence. Thorough geomechanics and fracture gradient were also assessed to identify requirements for managed-pressure drilling and for backup designs. The third key area is well integrity, productivity and injectivity where sand production and fines migration risks need to be addressed through well completion strategy. The reservoir management plan must also reflect realistic production and injection plans and data crucial for monitoring. The fourth key issue is with regards to subsurface complexity in deepwater turbidite environment with risks to production attainability vis-ร -vis reservoir connectivity and compartmentalization issues. A no-stones-unturned approach was taken integrating available static and dynamic data to estimate a robust recoverable volume. The fifth critical area is well startup and unloading procedures, which is important for well productivity. Model iterations were needed to conduct methodical well bean-up to eliminate risk of fines movement. Application of lessons learned in these 5 key areas led to robust development plans with mitigations for risks common to deepwater developments offshore north Borneo. For flow assurance strategy, the evaluation led to dual-loop design, proactive artificial lift strategy and optimum water injector locations. Drilling requirements are identified for MPD and backup slim-hole designs. To ensure productivity and injectivity, long highly deviated wells, with downhole sand mitigations, are designed for maximum contact and reduced required drawdown. Skin factors were applied in subsurface modeling as observed in other fields to risk the production targets. The model was also calibrated with dynamic data gained from well tests and pressure points to provide realistic production estimates, with a well sequence plan to observe actual performance and optimize next well locations if necessary. For well startup procedures, model iterations guided by analogue fieldsโ experiences led to optimum startup designs for L & B. These 5 key lessons learned areas are critical in deepwater development plans to ensure technical robustness during development stage to protect high investment value.
- Asia > Malaysia > Sabah > South China Sea (0.34)
- North America > United States > Texas (0.28)
- Asia > Malaysia > Sabah > South China Sea > Sarawak Basin > Baram Delta Province > Block G Production Sharing Contract > Block G > Malikai Field (0.99)
- Asia > Malaysia > Sabah > South China Sea > Sarawak Basin > Baram Delta Province > Block K > Kikeh Field (0.93)
- Europe > United Kingdom > North Sea (0.89)
- (3 more...)
Limbayong: Decoding Industry Top Decile Reservoir Complexity for Marginal Deepwater Development
Mohamed Najib, Mohamed Aiman (PETRONAS Carigali Sdn. Bhd) | Phoon, Yong Ken (PETRONAS Carigali Sdn. Bhd) | Wan Shamshudin, Wan Fatimah (PETRONAS Carigali Sdn. Bhd) | Mustapa, Shazana Sofia (PETRONAS Carigali Sdn. Bhd) | Khalid, Aizuddin (PETRONAS Carigali Sdn. Bhd) | Yusof, Yunus Alwi (PETRONAS Carigali Sdn. Bhd)
Abstract PETRONAS Carigali (PCSB) has developed a solution to monetize industry top decile worth reservoir complexity in the deepwater environment via Limbayong field, Malaysia. The field complexity is acknowledged by Independent Project Analysis (IPA) as industry top decile reservoir complexity due to severe elongated structure (30km length, 2.5km width) with varying faults frequency, vertical intercalation of thin-bed, thick sand reservoir and lateral compartmentalization which impend effectiveness of well drainage and pressure maintenance. The four (4) appraisal wells result since 2002 give diverse subsurface understanding, indicated possible different depositional model and greater degree of complication. This paper describes the key development challenges and strategies that significantly improve the field value proposition for FID. PCSB pivoted to focus assessment on low realization case for development. It generated advanced reservoir mapping to simulate sand distribution and concentration through incorporated faults re-interpretation, refined grid resolution, and change of facies prediction, increasing the stratigraphic compartments. The team performed integrated subsurface-surface flow assurance modeling and validated turndown limit for production and operation. Subsequently, iterated concepts for incremental reservoir recoverable by high-grading producer-injector pairing, wells-facilities design provision for a base, upgrade, or future tie-in. The team formulated industry collaboration (IC) studies in each FEL phase with drivers for deepwater technology enablers implementation in EPCIC primarily via concept selection, engineering standardization, and design competition. Each distinct concept is ratified with project economics group value chain evaluation and stakeholdersโ alignment. The breakthrough signifies merit in the key strategies and templates to overcome similar-scale project complexity with viable business cases. The IC affirmed cost proposition of 20 to 30% lower than industry average for deepwater wells and facilities, ensuring it to be positioned in top quartile project performance. It re-defined minimum technical design and demonstrated a prominent value trade-off for scaling-up concepts. It drives momentum to monetize high complexity reservoirs even further in the deepwater environment, which otherwise remains undeveloped. There is potential for replication throughout nearly 800MMboe scattered fields within deepwater offshore Sabah, Malaysia. Deepwater offshore has a niche role in bridging global transition between energy mix offering and net-zero economy target. It produces among the industry's smallest carbon footprints yet with high economic efficiency. Consolidated and efficient development strategies accelerate the decarbonization pathway. It advocates a hybrid capital project management model to manage extreme uncertainties with design thinking, lean startup, and agile approach.
- North America > United States > Texas (0.69)
- Asia > Malaysia > Sabah > South China Sea (0.35)
- Geology > Sedimentary Geology > Depositional Environment (0.47)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock (0.34)
- Asia > Malaysia > Sabah > South China Sea > Sabah Basin > Block G > Limbayong Field (0.99)
- Africa > Middle East > Libya > Al Wahat District > Sirte Basin > Sabah Field (0.98)
_ This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper OTC 31413, โApplying Downhole Sand Control for High-Rate Gas Completions in Deepwater Malaysia,โ by Elvy Jose Samuel, SPE, Mohd Faizal Yusoff, and Phil Bee, PTTEP, et al. The paper has not been peer reviewed. Copyright 2022 Offshore Technology Conference. Reproduced by permission. _ Designing and delivering a successful completion in a subsea high-rate gas deepwater environment is a great challenge in upstream field development. The complete paper covers the sand-control design and execution techniques applied to four high-rate gas wells in the operatorโs Block H development in the deepwater region of Sabah offshore Malaysia in 2020 and 2021. Field Background PTTEPโs Block H gas development is a multifield phased subsea development designed to deliver gas to Petronasโ floating liquefied natural gas (FLNG) project known as PFLNG2. The Block H field is in the South China Sea in water depths between 1150 and 1400 m. The first phase (Phase 1A) of the project was executed in four wells between the Rotan (three wells) and Buluh (one well) fields in the midsection of the Block H development. The reservoirs completed in Phase 1A were deepwater slope turbidite sands deposited during the Late Miocene and contain high net-to-gross reservoirs. Based on evidence from sonic logs and rock-mechanics testing performed on rotary side-wall cores and fullbore cores, all targeted reservoirs required robust sand control. Openhole gravel packing (OHGP) was chosen as the recommended sand-control technique for the high-rate gas application, and the four wells were drilled nearly vertically, with high water standoff height as a mitigation against early water coning. The drilling and completion operations were completed in a batch completion strategy in which all top holes were drilled to the top of the targeted reservoir, followed by the batch completion of all wellsโ lower completion phase, then the batch upper completion and well cleanups. The wells were placed on production in Q1 2021 to PFLNG2, achieving the targeted rates per well of 80 MMscf/D solids-free.
- Geology > Rock Type > Sedimentary Rock > Clastic Rock (0.71)
- Geology > Geological Subdiscipline > Geomechanics (0.70)
- Geology > Sedimentary Geology > Depositional Environment > Marine Environment > Deep Water Marine Environment (0.55)
Abstract Limbayong field situated in Sabah, Malaysia is operated by PETRONAS Carigali and is the company's first deepwater operated asset owned and operated by PETRONAS. Limbayong is a flagship project and strategically aims to be the deepwater hub for East Malaysia, particularly Sabah. The first phase of development is to start in Q1 2023. One of the campaign objectives is to produce from the deepest reservoir. However, the recently updated geomechanics model shows that there is a need to drill through with an extremely narrow drilling margin window (less than 0.5 ppg) even at the surface section for some of its wells. Most of these deep wells are required to be drilled in highly deviated and in the direction of the minimum horizontal stress. This poses an increased risk of stuck pipe due to hole instability, differential sticking, and skin damage due to high overbalance pressures, which makes drilling these wells challenging and costly. A mechanical earth model is initially developed based on Limbayong offset. The model has gone through an evolution with the recent model being updated to better fit observation in sand locally and regionally in recent wells drilled. The new reconstruction model significantly reduces the drilling window gap, thus MPD (MANAGED PRESSURE DRILLING) is required to meet the well objective and minimize drilling risk. By developing and applying those models, it helps to determine the safe operating downhole pressure limits and to effectively assess the drilling risks associated with the planned wellbore orientation. By accurately determining the required bottomhole pressure to prevent wellbore stability problems, managed pressure drilling technology can be implemented to provide improved drilling hazard mitigation by enabling reduced overbalance pressures, constant bottomhole pressure, and faster reaction time by instantaneously adjusting downhole pressures. This work underscores the development and usage of the advanced multi-phase model to simulate gas influx transport and its effects on BHP (Bottom Hole Pressure) during MPD operations. DrillBench hydraulics modeling was performed to determine the mud weight requirements to be used with the MPD system. Using the lowest MW (Mud Weight) possible to maximize the drilling window and flexibility was implemented as part of scenario simulation. This paper presents a case study where a holistic approach, combining geomechanics and drilling technologies were employed to address the drilling challenges specific to unconventional and naturally fractured reservoirs. Ultimately, this approach helped to mitigate stuck pipe issues, while proposing an engineering-based methodology to reduce losses by using MPD, hence providing a roadmap to optimized drilling and mitigation of hazards with associated Non-Productive Time (NPT).
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > Asia Government > Malaysia Government (0.45)
- Asia > Malaysia > Sabah > South China Sea > Sabah Basin > Block G > Limbayong Field (0.99)
- Africa > Middle East > Libya > Al Wahat District > Sirte Basin > Sabah Field (0.98)
Remediation of A Complex Blockage for Gumusut-Kakap Subsea Flexible Flowline from a System Perspective
Gwee, Yong Chin (Sabah Shell Petroleum Co Ltd) | Chin, Grace (Sabah Shell Petroleum Co Ltd) | Chan, Chee Hou (Sabah Shell Petroleum Co Ltd) | Chua, Lee San (Sabah Shell Petroleum Co Ltd) | Ling, Jason (Sabah Shell Petroleum Co Ltd) | Wu, Yvonne (Sabah Shell Petroleum Co Ltd)
Abstract A subsea production flexible flowline in Gumusut-Kakap field was found blocked in March 2021 during a routine production well-flowline switching/alignment operation. Further evaluation showed that the blockage was caused by the formation of hydrate and gel over the 1.3km length of the flexible flowline, as the live crude and water were left stagnant and untreated in the flowline over a prolonged period. This paper covers the remediation strategy and the associated challenges from a System perspective, which successfully unblocked the flowline within a relatively short period of time. The condition of the blockage in the flexible flowline was simulated using a commercial multiphase dynamic software to ascertain the phase distribution and hence allowed the estimation of the location and length of hydrate, gel, and emulsion in the flowline which has a downward inclination of circa 50 meters height. Heating (from production well), methanol (MeOH) soaking and flowline depressurization were planned and executed. In addition to the technical methodology, the System-wide aspects were also considered for the effective and optimum execution of the remediation activities which include attempting to fulfill the production commitment, abide by the subsea hardware and flexible flowline integrity envelope, and consider the impact of the remediation operation on other operations at the Gumusut-Kakap installation. The MeOH soaking, flowline depressurization and pressurization successfully remediated the blockage over the period of weeks. Positive results were observed at the start of the remediation when the targeted location for MeOH contact and depressurization were identified via field trial. One of the key challenges is the time factor in which to ascertain the "appropriate" waiting time for the flowline depressurization, as the remediation involved partial shut-in of the prolific production wells. A holistic System engineering approach is critical to the successful remediation of the blockage, integrating the key technical requirements as well as the soft and non-technical aspects to deliver optimum and net positive value for the asset.
- Asia > Malaysia > Sabah > South China Sea > Sarawak Basin > Baram Delta Province > Block K > Kakap Field (0.99)
- Asia > Malaysia > Sabah > South China Sea > Sarawak Basin > Baram Delta Province > Block K > Gumusut Field (0.99)
- Asia > Malaysia > Sabah > South China Sea > Sarawak Basin > Baram Delta Province > Block J > Kakap Field (0.99)
- Asia > Malaysia > Sabah > South China Sea > Sarawak Basin > Baram Delta Province > Block J > Gumusut Field (0.99)
Abstract Designing and delivering a successful completion in a Subsea High Rate Gas Deepwater environment is known to be one of the most challenging aspects of a Field Development. For the specific case of high rate gas wells with reservoirs requiring sand control, it makes the completion reliability and longevity an uncompromising prerequisite, as it is well known that formation solids moving at high velocity through the wellbore can drastically affect the functionality and integrity of downhole equipment as well as the subsurface and production facilities. In addition, to the previously mentioned aspects, the complexities and costs associated with Well reentries and Workovers in a Subsea Deepwater environment can quickly erode the overall financial viability of a development program. This paper covers the sand control design and execution techniques applied to four (4) High Rate Gas Wells in the PTTEP's Block H Development in the Malaysian Deepwater region of Sabah, between 2020 and 2021.
- North America > United States > Texas (0.28)
- Asia > Malaysia > Sabah > South China Sea (0.15)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock (0.70)
- Geology > Geological Subdiscipline > Geomechanics (0.69)
- Well Completion > Sand Control > Sand/solids control (1.00)
- Well Completion > Sand Control > Gravel pack design & evaluation (1.00)