bluuebunny/crossref_metadata_2025_split huggingface dataset:
A New Technology Approach Using Permanent Chemical Tracer for Water Source Identification in Ujung Pangkah Field
Authors: Eviany Ameria , Mario Cio Cio , Hakim Arief Lukman , Nugrahanto Anang , Pramana Harris , Murtani Anom Seto , Rashed Rasha , Koumouris Steve , Huseby Olaf 
Published: October 2023

Abstract
One of the most common challenges in oil and gas production today is the multiphase production from a well with a high-water ratio continuously increasing along with the natural depletion of reservoir pressure. Wells in Ujung Pangkah (UP) field, generally completed in order to segment the flow. This is achieved by using Inflow Control Device (ICDs) and Sliding Sleeve Doors (SSD). This completion strategy aims to overcome the water continuity problem that creates a steeper drop in oil or gas production. As part of reservoir surveillance and water source identification, typically, a Production Logging Tool (PLT) is utilized as the standard technology. Nevertheless, it requires an equipment unit to convey this PLT technology into production tubing up to the target depth. To optimize production in wells completed with horizontal with multi sections, determination of water sources is essential to make decisions on intervals to isolate in order to minimize water production rate. SAKA Energi Indonesia, as the operator of Pangkah PSC, has applied another approach to this water source identification known as permanent installed chemical tracer.
Considering the dependency on equipment, tool, and cost of running conventional PLT technology, SAKA has implemented chemical tracers embedded into each well completion's ICDs. The tracer technology was installed in WPA-X and used twice, to identify the ICD sources responsible for the incoming water. The installed chemical water tracers (one unique tracer chemical per inflow section) can detect that specific ICD's contribute to flow – simply from pure mass-balance considerations. Furthermore, if the well is shut-in and restarted, the time-evolvement of tracer signals and differences in arrival-time for individual signals can be used to assess the zonal inflow contribution across separate inflow points along the well.
Compared to other methodologies (e.g. production logging tools), the tracers can provide results during unrestricted flow (i.e. without any tool affecting the flow). Other key benefits of this permanent solid tracer in the well are intervention-less activity that reduces cost and continuous reservoir monitoring. For short-term advantages, the inflow tracer data could provide quantification of each zone contribution, water break-through identification, and indirectly get information on packer integrity and other completion design performance. For mid-term benefit, the result could drive an action plan to eliminate water production in WPA-X. This tracer technology is a flexible technology with several applications to support specific decisions over a long time period in the well's life.
Recover the Well Integrity Issue Successfully in Combined Surface Casing and Intermediate Liner Annular for Offshore Re-Entry Well, Case in STS Platform - East Kalimantan, Indonesia
Authors: Laksono Setiadi , Palgunadi Haryotomo Budi , Aristya Ramadhana , Sianturi Bidner 
Published: October 2023

Abstract
Sejadi re-entry well is located in STS platform, offshore East Kalimantan, PT Pertamina Hulu Kalimantan Timur. SJ-2 well slot has been selected as re-entry well for drilling development from 5 existing well slot at the same location. As part of Stacked Template Structure (STS) where the SJ-2 conductor is used as one of platform leg, surface and wellbore integrity is important to maintain platform stability as well as well integrity.
During well preparation work by using Hydraulic Workover Unit (HWU), the leaking was observed on the surface through annular 13-3/8″x30″ casing. In term of surface wellhead, observed the unihead has tilting indication which may degraded related of structural capacity. Both of the integrity issue need to be recovered prior to proceed re-entry drilling operation. In order to get optimum work capability, the well preparation work has suspended and for well integrity recovery work it will be performed by Jackup rig.
The unihead tilting issue need to be verified and to ensure the structure capacity is sufficient, some stiffeners were welded on the unihead to 30″ casing housing plate as a supporter. In term of wellbore integrity issue, the recovery plan has been developed with the scope as follows; leaking point identification, remedial cementing which include the installation of additional 9-5/8″ as "suspended" tie back casing, and barrier verification test.
This paper is describe the process to recover both surface and wellbore well integrity issue by Jackup Rig, in consideration to optimize operation timeline, chance of success and rig daily spread cost. This practice has successfully implemented safely, to provide well integrity assurance to be able to continue the operation until put on production phase.
A Collaborative Solution in Optimising Deepwater Well Placement in Challenging Seabed Environment with Close Proximity to Mud Volcano
Authors: Mohd Safari Lai Harni Farihah , Mohd Sukri Eskandar 
Published: October 2023

Abstract
Deepwater development drilling is going to be one of the main keys to revitalize oil and gas industry in Malaysia as most of the shallow water reserves are heading towards their end-of-field life. However, this region's deepwater shallow seismic studies and findings from exploration and appraisal drilling shows that the subsea environment here comprises set of challenges, that if not carefully tackled, will turn the project to be un-attractive and irrelevant. This paper will explain the "collaborative" method that is used by the Deepwater Field Development Plan team during the well planning phase in detail and show how this method helped the team overcome a set of challenges efficiently, making the project able to progress to next stage.
The approach is to utilize different technology platforms where multiple disciplines gathered in collaborative well planning sessions to share their expertise in determining the optimum well placement that better suit the well trajectory, subsea facilities equipment placement and pipeline installation; whilst at the same time fulfilling the subsurface target requirement. This development field encompass enormous challenges such as presence of shallow gas, hydrates pocket, seafloor roughness, slope and slope failure, mud volcano, gulleys and pockmarks. All concerns are evaluated in detail on their risk ratings and associated impacts on the well design. The entire well plan is shared live during the session for better view and understanding, and any amendment is done and evaluated in real time to accommodate all parties’ requirement.
In conclusion, this paper will discuss the step-by-step method used to achieve the best engineering design for subsea development producer and injector wells in a complex seabed environment. Iterative collaborative sessions have proven to provide a platform to achieve a collective agreement to safely place the development wells efficiently. These sessions are key to unlock the opportunities and identifying threats at a very preliminary stage of the Field Development Plan (FDP). This paper would provide a greater insight of deepwater development well planning strategy in a challenging oil and gas environment with lessons learnt and best practices recommendation for future complex subsea FDP planning references.
Success Story of Repairing Casing Leak Near Surface Using a Bandage Cementing Technique in Central Sumatra Basin
Authors: Kurniawan Imron Fajar , Tarigan Jan Hendri , Hamdani Nanang Lutfi , Dova Rudi , Nataliawati Nurul Ayu 
Published: October 2023

Abstract
During the water injector workover campaign in 2018, some casing leakage near the surface was identified (depth range 10 to 300 ftRT). Several attempts were made to seal the leakage, but none of them succeeded. In response to investigation, a specific cementing technique was developed, called "bandage cementing", and it was successful in repairing casing leaks near the surface with over 75% success rate.
The focus of this technique is to build a column of cement in annulus between production casing and surface casing to create a "bandage" covering all leaking points in production casing. To build it, a cement evaluation log was run to investigate the presence of cement in annulus surface-production casing. A perforation gun was then run into the well to make some holes in production casing below leaking points. Injectivity and communication test was then performed to check the connection between perforation hole and leaking points and casing valve in surface. Once communication confirmed, cement retainer was then deployed to perform cementing jobs inside production casing and in annulus surface-production casing. The goal is to fill the void in annulus between surface and production casing with cement to build a cement column covering the casing leak.
This repair casing technique was applied to 4 (four) water injector wells with casing leak problems. The repair job succeeds to seal the casing leaks and all wells were put back on injection. They passed the pressure test and confirmed the leak was completely sealed. The key success for this repair casing method lies in how well we can place cement columns to surround the leak points from both below and above the leak. Several observations include whether the injectivity connection could be established between leaking points, perforation hole and casing valve and how much barrel of cement could be placed behind the casing are the supporting factors to achieve it.
The goal of this paper is to provide an alternative to casing repair for wells with casing leak problems near the surface which are usually very difficult to repair and take a lot of time on the rig to repair.
Semut Field Enhancing Production: Integrated Analysis to Reveal Thin Layer in Thick Sand Formation on Brown Waterflooded Field
Authors: Evelyn Katerina , Ustiawan Arief Budiman , Ramadhani Urfi , Moestopo Hendar Soeharnoko , Masyhuri Ali , Afton Muhammad , Fardiansyah Iqbal 
Published: October 2023

Abstract
Semut Field is a small brown field located in Central Sumatra basin produced since 1966 and waterflooded since 2009. Semut Field production has already depleted at 1/10 from its peak production and produced with high water cut. Earlier production strategy had been targeted at waterflooded thick and good permeability (~1 Darcy) reservoir and produced comingle. Deep dive and comprehensive analysis on G&G and rock properties on sand basis will be the answer to reveal any hidden opportunity on mature reservoir to increase oil production in Semut Field.
The approach to increase oil production is done by using and analyzing new data from Carbon-Oxygen (CO) logs and new infill well in 2021 to map the unrevealed potential of remaining by-passed oil. This field opportunity is hidden in lower permeability thin sand (&lt;300 mD) with limited distribution that was previously overlooked in wide scale stratigraphic analysis. Comprehensive analysis of high-resolution stratigraphy also could figure out some thin sand that separated from the main sand lobes in each formation. More analysis on historical production and completion of old wells that have thin sand opportunity should be done to find out the earlier sand performance.
High-resolution stratigraphy approach analysis by layer sand is proven for revealing hidden opportunity in Semut Field. The remaining oil was found stored in a thin sand layer with perm ~200 mD which is lower than the average overall sand formation permeability. There are two main recommendations to unlock the opportunity at Semut Field based on the analysis result. First, completion strategy by selecting and precising perforation depth is critical since the separation between sand layer could only be between 2-3 ft shale. Second, production strategy by producing single or commingle with other sand that have similar PI and reservoir pressure. This approach gives outstanding results with oil gain 1,600 BOPD and oil cumulative 28 MBO within 1 month production, it is doubling Semut Field production.
This effective approach could be an alternative strategy to be applied in other Mature waterflood field or Primary field. This is a good case of how workovers on old wells can increase oil production in cheap way and dramatically extended good economic life.
Exceptional Length of Coring Recovery in a Very Loose Sand or Unconsolidated Formation in South Natuna Sea Block B at 8-1/2" Hole Section with a Conventional Full Closure System
Authors: Wales Benny Richard , Aribowo Triadi Herwasto , Hartanto Daru Mulyo , Darmawan Kurnia , Putranto Heru , Panjaitan Julianta 
Published: October 2023

Abstract
The South Natuna Sea Block B field is located in the waters of the Riau Archipelago and is a large and fragmented PSC that covers a number of oil and gas fields in the Natuna Sea, of which a few are currently operated by Medco E&P Natuna Ltd. Coring Service is one of the processes that is required by Medco E&P Natuna Ltd. for unconsolidated formations as the target reservoir zone.
Unconsolidated formation is very challenging to core, especially with the standard conventional system, as the core could slide and slip off from the inner barrel assembly of the Standard Conventional System while pulling out of the hole while the whole coring assembly is in progress. A Full-Closure System technology with a Double catcher assembly (Clam Shell Catcher and Spring Catcher as the main component) is necessary to address the problem.
The full closure system technology, which was created specifically to catch any unconsolidated formations, has gained widespread acceptance for its effectiveness in a variety of fields, particularly in Indonesia. Even when the Full Closure system is assembled and run in the hole, anomalies like core jamming and milling the core are difficult to detect at the surface gage while coring is taking place at unconsolidated formations.
The challenge is further increased by the 90-foot length of the core that must be retrieved in a single-run in order to save cost by reducing the number of trips. This plan goes against the best advice or rule of thumb given by the majority of coring services, which stated that when coring, especially in an unconsolidated formation, a shorter length of barrel is highly recommended, such as per joint or only 30 feet to be done in one run, for example, for a Total of 3 (three) × 30 feet to retrieve the entire target of 90 feet, in order to avoid any unforeseen anomalies.
Since vibration always increases the likelihood of core jamming, a shorter core barrel could potentially cause less vibration while coring is taking place. If this happened, the core would then be milled. Therefore, a shorter barrel always presents a lower risk of losing precious data samples if core jamming and core milling anomalies ultimately occur undetected.
This paper is made to inform, demonstrate, and discuss how Full-Closure System technology and certain key procedures that are strictly followed and monitored could mitigate the potential hazards or risks mentioned to Successfully Core the 90-foot core target in one run at an Unconsolidated formation and be the first to ever do it in that length, especially in Indonesia.
Performance Improvement in Wellbore Side-Tracking: A Case Study of Dual-Casing Exit in Mahakam Offshore
Authors: Sinaga Rahmat , Hutahaean Ray Henry , Andhika Lutfi , Nurmida Arrofi , Haryasukma Kresna Prabu 
Published: October 2023

Abstract
In the last two years, an operator has been performing drilling and completion from an existing well's slot to access geological targets means a sidetrack operation is conducted in a cased hole. This initiative needs to be efficient in budget-wise and regulation as well.
Cased hole sidetrack operation can be challenging, particularly when the milling assembly has to cut dual-casing due to the existing well condition and the geological target requirement. The centralizer and casing collar position inside the wellbore is considerably to select the kick-off point and optimize the well's trajectory. Besides, the work sequence and the Bottom Hole Assembly (BHA) selection are significant to avoid costly multiple trips. Moreover, a unique challenge to ensure the window is in good condition when the wireline logging job needs to conduct in an open hole.
This paper provides a case study of performance improvement of dual-casing sidetrack in 9.625 in and 13.375 in within the last 2 years. The study was started by modeling the BHA which generates the least amount of vibrations to pass through the window. Further, a comparison between a bi-mill and a tri-mill BHA includes the position of each mill and the milling parameters to achieve the most efficient result. Doglegs severity within the interval depth of setting the whipstock is also taken into account since the dogleg through the window can create additional issues. There was no casing collar locator logging job run as the tool will not able to identify the collar position in the 13.375 in the casing string. Therefore, historical data on the casing tally and the well's information has become essential for determining the whipstock setting depth.
This integrated and collaborative planning has resulted in a successful dual-casing exit operation during the last two years in Mahakam offshore. Improvements made in the engineering and operations have successfully overcome the challenge identified in the initial period of the campaign.
Maintain Oil Production Equal to 7,600 Bopd Through Vsd Excellent Workflow and Best Practices in 100 ESP Wells
Authors: Alkahfi Sayid Habibi , Purba Monas Octavianus , Ifani Refni , Garini Sistha Ayu , Wusodo Winoto , Junaidy Ichwan 
Published: October 2023

Abstract
There are currently more than 50 active fields and 1,000 ESP wells in Light North Area. Those fields are having various problems both surface and subsurface. Sanded, gassy, scale, limited productivity, high temperature, congeal are common problems in this area which impact directly to well failure and loss production.
An initiative to build workflow and best practices to reduce well failure and improve production utilizing Variable Speed Drive (VSD) had been started since 2016. There are more than 100 ESP wells installed with VSD as per today across this area. It needs effective surveillance and monitoring workflow to be managed to keep production level while minimizing failure at the same time. Installation process, routine review and dismantle decision included all related surveillance data are become part of integrated workflow.
The number of VSD has been increasing significantly since 2018 from 60s to 100s in 2023. Associated oil from these VSD is around 7,600 BOPD. It is a significant number to be maintained to support the government target as 1 MMBOEPD in 2030. Excellent coordination review among Subsurface, Well Reliability, Operations, Well Test and ESP Vendor are key success to manage these VSD wells properly. The team decided to set monthly VSD review. Semi-automatic and established processes have been put in place to monitor all the process. Activity cycle time has been improving to ensure less oil loss during installation and dismantle job. Several best practices related to ESP and VSD design, setting and modification are also provided in this paper.
Field B Oil Recovery Improvement Through Autonomous Inflow Control Device (AICD), A Case Study
Authors: Ariffin Mohd Hafizi , Mansor Mohd Najmi , Marimuthu Raam , Salleh Fairus Azwardy , Wahid Ali Nurul Athirah , Guillory Ryan 
Published: October 2023

Abstract
In a thin oil column environment, the team needs to look for a way to monetize this oil with optimized cost and reduce the risk of unwanted fluid (gas and oil). To make matter worse, the reservoir drive mechanism is mainly gas-cap expansion with moderate aquifer support. The team has looked at several methods to delay this water breakthrough i.e., standoff from Oil Water Contact (OWC) and Gas Oil Contact (GOC), and Autonomous Inflow Control Device (AICD).
There are two AICD types considered during the preliminary design stage which are the Fluid Diode Type and Rate-Control-Production (RCP) type. The team performed a cost-benefit analysis on these two types of AICD.
AICD RCP type was selected to be the best way forward for this kind of reservoir. AICD RCP type should be able to control the horizontal drawdown thus reducing the unwanted fluid production. With this type of AICD, the viscosity contrast between oil and the unwanted fluid is important. With the viscosity contrast of 0.6 cp for oil and 0.5 cp for water, the viscosity contrast is considered low. The AICD does not work effectively to reduce water production. Thus, it is important to have a good OWC standoff to delay water production.
Coupled with the reservoir dynamic model, sensitivity analysis was performed with several cases to improve the team's understanding of the AICD impact on the oil recovery. Below are cases run to ensure the best configuration were applied for each completion. Gas Oil Ratio (GOR) impact on the oil recovery with and without AICDWater Cut impact on the oil recovery with and without AICD.OWC and GOC standoff impact on the oil recovery with and without AICDNumber of AICD joints impact on the oil recovery with and without AICD
The utilization of AICD technology is predicted to significantly improve oil recovery with the expected reserve to increase around 10-25% while delaying the unwanted fluid production.
The field has an existing Inflow Control Device (ICD) well and 2 AICD wells just completed in 2022. With this, the team may analyze the benefit of the AICD compared to ICD. In addition, to ensure good recovery from the reservoir, a mud breaker was pumped to reduce the drilling mud damage in the open-hole section. Furthermore, oil and water tracers were installed to ensure water production location on the AICD open hole section.