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Collaborating Authors
Malaysia
Making Wells Safer; Rectification of High Annulus Pressure via Diagnostic and New Technologies Through Annulus Intervention Method
Osman, Abdul Afif (PETRONAS Carigali Sdn Bhd) | Azman, Aulfah (PETRONAS Carigali Sdn Bhd) | Sipangkui, Rayner Brian (PETRONAS Carigali Sdn Bhd) | Nazirmuddin, M Nazrul Shahril (EXPRO Group) | Aripin, Izura (PETRONAS Carigali Sdn Bhd) | Utta, Arie Muchalis (PETRONAS Carigali Sdn Bhd) | Sujavudin, M Ridhuwanuddin (PETRONAS Carigali Sdn Bhd) | Sy Ahmad, Sy M Shahril (PETRONAS Carigali Sdn Bhd)
Abstract Sustained annulus pressure is an increasingly common well integrity issue encountered particularly in aging platforms. The issue is normally discovered via periodic wellhead maintenance programs or during monitoring by the production team. Subsequently, the wells integrity team will pursue well diagnostic via annular pressure diagnostic by manipulating and creating specific conditions to acquire information on the potential leak rate, leak path, and source of the leak. The probable culprit of the tubular integrity issues is due to completion or casing leakages, or failed cement conditions. The generic rectification technique available varies from rig to rigless method. Considering the low economic of the field & remote jacket location with a small footprint and limited crane capacity in Sabah waters, either the rig or workover option can be unfavorable. Therefore, the options available to remediate the sustained annulus pressure are limited considering the platform's design and operational setup. Historically, the team has attempted with a conventional pump and lubricate the annulus to mitigate the symptoms. However, the effectiveness was questionable as the pressure kept creeping up within a short period which urged the team to look into better technology solutions. With the limitations above, the team warrants a new holistic approach to resolve the sustained annulus issue. Annulus Intervention System (AIS) provides better fluid conveyance and circulation for better fluid displacement at the targeted depth. The AIS system has a smaller footprint as compared to a pumping or workover unit which is a major advantage for a small and remote platform directly applicable to the target Sabah asset. This paper will table out the step-by-step method that has been taken by the team to ensure the AIS system is engineered and tailored to rectify the sustained annulus pressure in a less than 500-meter square deck space.
First Experience Matter: The Valuable and Great Learnings from Unfavorable Mud Acid Stimulation in S Field Gravel Pack Wells, East Malaysia
Bakar, Hasmizah (Petronas) | Ravichandran, Narindran (Hibiscus Petroleum) | Hassan, Hamidah (Petronas) | Abu Bakar, Mohamad (Petronas) | Idris, Khairul Nizam (Petronas) | Masoudi, Rahim (Petronas)
Abstract Most of the S oil field producers experienced rapid decline in production and this is suspected due to fine sediment particle migration and plugging. The S field team had carried out external formation damage study as they have no expertise and field experience to determine the damage mechanism and evaluate the best acid treatment recipe for their formation damage. Recently, mixtures of traditional hydrochloric and hydrofluoric acids have been used for the removal of near-wellbore damage in S field sandstone formations. The stimulation campaign in this field which has turbidite reservoir, high clay content predominantly by kaolinite and illite with high siderite mineralogy applied both bullheading and coiled tubing squeezing techniques. The treating fluid selection is highly dependent on mineralogical data and laboratory works. Based on the core flood testing performed, high strength mud acid is chosen as the main treatment fluid and gave superior result in permeability recovery as compared to milder organic acid and HF. Unfortunately, the actual field stimulation turned out to be opposite from the core flood testing outcomes. The situation is worsened in multistage treatments, which traditionally involve many repeat stages of preflush, main treatment, overflush and diverter. The mud acid stimulation prompted more water production and fine migration that is ended up with production curtailment. Only one out of four of the treated candidates resulted significant gain after gas lift valve change took place. This paper also will outline the reviews on results of laboratory testing and field actual performance together with the recommendations for future improvement. Stringent candidate selection, improved treatment fluids cocktail, operational challenges such as unanticipated longer flow back period, post treatment unwanted precipitation, ineffective diverter placement and skin build up post treatment are among of the learning points captured in this paper. From this unfavorable mud acid stimulation campaign which cost USD4million value leakage, our team comes out with best practices for future stimulation and key learning to share with industry colleagues who has no field background to combat with fine migration issue in their sandstone asset. Laboratory works is not the only paramount to any stimulation, success in stimulation is a journey, not a destination. The doing is often more important than the outcome.
- Geology > Mineral > Silicate > Phyllosilicate (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (0.91)
Novel Candidate Screening and Successful Implementation of Stimulation in Screen Completed Wells to Double Production in Brown Fields – A Case Study from Offshore Malaysia
Anand, Saurabh (PETRONAS Carigali Sdn Bhd) | Mat Khair, Nusheena (PETRONAS Carigali Sdn Bhd) | Azhar B. Abu Bakar, Khairul (PETRONAS Carigali Sdn Bhd) | Madon, Bahrom (PETRONAS Carigali Sdn Bhd) | Kin Chun, Kok (PETRONAS Carigali Sdn Bhd) | M. Adib, M. Syamil (PETRONAS Carigali Sdn Bhd) | Rahim, M. Ikhlas (PETRONAS Carigali Sdn Bhd)
Abstract Majority of wells completed offshore Malaysia have downhole screens installed for sand and fines control. It is however observed that the PI of most of these wells drop multifold times within first few years of production. This paper illustrates the workflow with novel technique of screening such wells for stimulation to restore well production. This paper will also illustrate a few examples of actual implementation of the stimulation jobs and the excellent results from these jobs. Hundreds of strings operated by PETRONAS in Malaysia Offshore across various fields have some form of downhole screen (standalone or as part of the gravel pack) installed to control sand and fines. Although these completions remain effective initially, but water break through results in significant PI decrease. It has been established that the predominant cause of this decline is the screen or gravel pack plugging by the fines mobilized by water which is followed in many cases by deposition of inorganic or organic scales. A workflow was developed using data from existing digital production monitoring system to identify wells showing the plugging behaviour. The workflow used several factors such as liquid rate decline, GOR, water cut, reservoir pressure, artificial lift performance etc to shortlist a list of wells on which a detailed nodal analysis was applied to estimate gains assuming 70% skin reduction. The wells which passed the workflow and showed maximum benefit from stimulation were then grouped together such that a campaign-based execution could be done to optimize cost. Detailed customized stimulation recipe for each well was prepared and optimized well level operation program was prepared. Optimization such as using bullheading technique instead of using coil tubing in some cases was done. Stimulation treatment in 4 of the wells has been pumped successfully with excellent results and an estimated 1,000 bopd total gains. The post job oil rate is double the initial rate in many cases and even 200% more in some of the cases. Post job nodal analysis suggests up to 90% damage skin removal in these wells. Optimized operation program and campaign-based execution coupled with other cost saving measures implied that the payback time was less than 1 month. PDG data from one of the wells was used extensively to evaluate pre & post stimulation well behavior. The high damage skin in the screen completed wells is one of the most pertinent issues which leads to significant production loss in wells offshore Malaysia. This paper details a quick and robust method to identify such wells for stimulation. The results from these stimulation jobs on candidate wells are very encouraging particularly considering the economics of the jobs. Following the success of the initial jobs, many more candidate wells have been lined up for execution in near future.
- Asia > Malaysia (1.00)
- North America > United States > Texas > Terry County (0.40)
- North America > United States > Texas > Gaines County (0.40)
- Europe > United Kingdom > North Sea > Southern North Sea (0.40)
- Energy > Oil & Gas > Upstream (1.00)
- Water & Waste Management > Water Management > Constituents > Salts/Sulphates/Scales (0.48)
- Africa > Middle East > Libya > Murzuq District > Murzuq Basin > Block NC 186 > Field A Field > Silurian Tanezzuft Formation (0.97)
- Africa > Middle East > Libya > Murzuq District > Murzuq Basin > Block NC 115 > Field A Field > Silurian Tanezzuft Formation (0.97)
- Africa > Middle East > Libya > Murzuq District > Murzuq Basin > Block NC 115 > Field B Field > Silurian Tanezzuft Formation > B27 Well (0.93)
Abstract Applications for Active membership have been received from the candidates listed below. This publication does not constitute election but places the names before the membership at large in accordance with SEG's Bylaws, Article III, Section 5. If any member has information bearing on the qualifications of these candidates, it should be sent to the SEG president within 30 days.
- Asia (1.00)
- Europe (0.88)
- North America > United States (0.56)
Artificial lift is a method used to lower the producing bottomhole pressure on a formation to obtain a higher production rate from the well. This can be done either with a positive-displacement downhole pump, such as a beam pump or a progressive cavity pump (PCP), to lower the flowing pressure at the pump intake, or it can be done by injecting gas with high pressure through a downhole gauge near the bottom of the well. The selection of the method depends on many factors such as reservoir characterization, completion design, and operating conditions such as pressure, temperature, and producing rate. In addition, production-fluid properties such as density and viscosity also play a role in the selection of artificial-lift methods. The market for artificial-lift systems is growing at a compound annual growth rate of more than 4.5% (Figure 1).
- Asia > Malaysia > Terengganu > South China Sea > Malay Basin > Block PM 6 > Dulang Field (0.99)
- Asia > Indonesia > East Kalimantan > Kutei Basin > Mahakam Block > Handil Field (0.99)
- Asia > Indonesia > East Kalimantan > Makassar Strait > Kutei Basin > Mahakam Block > Mahakam Field (0.97)
Discovered in 2011 offshore the Malaysian state of Sarawak, the Kasawari sour gas field is today a symbol of Southeast Asia's energy challenge. Petronas is eyeing next year for first gas. By 2025 it hopes to see 900 MMscf/D flowing from the field to its sprawling Bintulu LNG export facility on the Sarawak coast. But what makes the field a regional and industry bellwether is not its natural gas. When peak output is reached, Petronas plans to stop venting and start capturing between 3.7 and 4 million mtpa of the CO2 that will be produced from the project's wells over the next 2 decades. That's more than 8% of the greenhouse gas emissions Petronas reported for all of 2020. And in more upstream-friendly terms, the injection target at Kasawari is roughly equal to 77 Bcf of gas each year.
- Energy > Oil & Gas > Upstream (1.00)
- Energy > Oil & Gas > Midstream (1.00)
- Government > Regional Government > Asia Government > Malaysia Government (0.81)
- Asia > Indonesia > West Papua > Bintuni Basin > Tangguh Field (0.99)
- Asia > Malaysia (0.89)
- Reservoir Description and Dynamics > Storage Reservoir Engineering > CO2 capture and sequestration (1.00)
- Health, Safety, Environment & Sustainability > Sustainability/Social Responsibility > Sustainable development (1.00)
- Health, Safety, Environment & Sustainability > Environment > Climate change (1.00)
- (4 more...)
Optimisation of Oil Production with RCP Autonomous Inflow Control Devices in a Field in Offshore Malaysia, A Case Study with Shell Malaysia
Krishnan, Thanushya (Sarawak Shell Berhad) | Sandhu, Harwinder (Sarawak Shell Berhad) | Lai, Chin-Lin (Sarawak Shell Berhad) | Konopczynski, Michael (Tendeka) | Moradi, Mojtaba (Tendeka)
Abstract During 2019 and 2020 the field operator conducted development campaigns in a thin oil rim carbonate reservoir offshore Malaysia. The horizontal development wells were expected to intersect heterogeneous formations with varying properties resulting in an uneven reservoir influx toward the wellbore. Oil production from these wells was expected to suffer severely from an early gas breakthrough. These challenges were recognized to be mitigated by deploying Autonomous Inflow Control Devices (AICDs), installed at reservoir interface along the horizontal section of the wells. The AICDs can manage the reservoir fluid influx entering the wellbore and therefore optimise the well performance. To improve oil production and ultimate recovery, AICDs were incorporated in the lower completion design for the development wells. The Rate Controlled Production (RCP) AICD was chosen for this application. It is an active flow control device, delivering a variable flow restriction in response to the properties of the fluid and the rate of flow passing through it. This paper summarizes the integrated technical learnings from this project. An integrated workflow was followed to design and deliver the AICD applications successfully for the operator in an offshore light oil reservoir with huge uncertainties in remaining oil thickness and reservoir properties. The wells with a horizontal length of ~6000 ft were drilled in a relatively thin oil formation. The well intersected different geological layers with different rock properties. The lower well completions comprised of RCP AICD valves, shrouded with debris filter screens with an in-situ gas lift system in the upper completions helping to lift the fluids to the surface. The wells were segmented into compartments with blank joints and swell packers and tailored AICD placements based on individual well's real-time log data to properly restrict the production of unwanted fluids. Through teamwork between the companies, the wells were successfully completed with AICDs. The final modelling was performed just in the time span between reaching target depth and running the completion. Over two years of production, the wells completed with AICD not only have not seen any problem in terms of solid production, but they have also successfully exhibited limited GOR development which enabled oil production optimization. A PLT was also run recently in one of the wells to analyze further the zonal contribution of each section of the well and how AICD has effectively choked back the gas in selective zones. The results show that the AICD completion ensured a balanced contribution from the entire 6000 ft long horizontal section in the well despite the heterogeneity of the carbonate reservoir and has potentially reduced the gas production significantly to enable more optimized oil production within gas offtake limits in the reservoir management plan.
- Asia > Malaysia > Sarawak > South China Sea (0.28)
- North America > United States > Texas (0.28)
- Research Report > New Finding (0.48)
- Research Report > Experimental Study (0.34)
- Europe > Norway > North Sea > Northern North Sea > North Viking Graben > PL 054 > Block 31/6 > Troll Field > Sognefjord Formation (0.99)
- Europe > Norway > North Sea > Northern North Sea > North Viking Graben > PL 054 > Block 31/6 > Troll Field > Heather Formation (0.99)
- Europe > Norway > North Sea > Northern North Sea > North Viking Graben > PL 054 > Block 31/6 > Troll Field > Fensfjord Formation (0.99)
- (12 more...)
Getting Serious with Net-Zero: Implementing Large-Scale Carbon Capture and Storage Projects in ASEAN
Lau, Hon Chung (National University of Singapore) | Zhang, Kai (National University of Singapore) | Bokka, Harsha Kumar (National University of Singapore) | Ramakrishna, Seeram (National University of Singapore)
Abstract As a region, the ten nations of ASEAN emitted 1.65 Gtpa CO2 in 2020 from the combustion of fossil fuels. Analyses reveal that ASEAN's renewable energy resources are low to moderate and unevenly distributed geographically. Furthermore, there are substantial sustainable issues related to hydropower and bioenergy. The current rate of addition of new renewable power capacity is too slow to allow ASEAN countries to achieve net-zero by the middle of the century. More tools, in addition to renewable energies, will be needed. It is found, however, that carbon capture and storage (CCS) is a key enabling technology to decarbonize ASEAN's fossil-fuel power and industrial plants and to produce blue hydrogen needed to decarbonize the industry sector. Furthermore, results of CO2 source-sink mapping exercises show that there is enough capacity in major sedimentary basins in ASEAN to permanently store two centuries of anthropogenic CO2 emission. Six first mover large-scale CCS projects in ASEAN with potential to mitigate up to 300 Mtpa CO2 from Singapore, Indonesia, Malaysia and Thailand have been identified. Furthermore, the steps needed to implement these CCS projects are also discussed.
- Asia > Indonesia (0.93)
- North America > United States > Texas (0.46)
- Europe > Norway > North Sea > Skagerrak > Oslofjord > Longship CCUS Project (0.99)
- Asia > Indonesia > Sumatra > Aceh > North Sumatra Basin > B Block > Arun Field (0.99)
- Asia > Vietnam (0.89)
- (8 more...)
Abstract As a region, the ten countries of ASEAN emitted 1.65 Gt of CO2 in 2020 which was 4.75% of worldwide emission. The biggest CO2 emitting nations were Indonesia, Malaysia, Thailand, Vietnam and Philippines. This paper conducts a detailed analysis of total primary energy consumption (TPEC) and CO2 emission profiles from these five countries as well as Singapore and Brunei (ASEAN-7). Analyses show that in 2018, TPEC of ASEAN-7 consisted of 35% oil, 29% coal, 19% gas and 17% renewables, whereas CO2 emission came 44% from coal, 39% from oil, and 17% from gas. Seven pathways for rapid decarbonization of ASEAN are proposed. They include: (1) increasing the share of renewable energies in power generation, (2) replacing coal by gas in power generation, (3) electrification of road transport, (4) hydrogen for marine transport, (5) biofuels for aviation, (6) blue hydrogen for hard-to-decarbonize industries, and (7) establishing regional carbon capture and storage (CCS) corridors to accelerate implementation of large-scale CCS projects.
- Europe > Norway (0.46)
- Asia > Brunei (0.37)
- Asia > Singapore (0.28)
- North America > United States > Texas (0.28)
- Europe > Norway > North Sea > Skagerrak > Oslofjord > Longship CCUS Project (0.99)
- Asia > Philippines (0.89)
- Asia > Indonesia (0.89)
Abstract Applications for Active membership have been received from the candidates listed below. This publication does not constitute election but places the names before the membership at large in accordance with SEG's Bylaws, Article III, Section 5. If any member has information bearing on the qualifications of these candidates, it should be sent to the SEG president within 30 days.
- Asia (1.00)
- North America > United States (0.80)