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Kalimantan
Eni has struck significant gas reserves with its Geng North-1 exploration well drilled in North Ganal PSC, about 85 km off the coast of East Kalimantan in Indonesia. Preliminary estimates indicate a total structure discovered volume of 5 TcF of gas in place with a content of condensate estimated up to 400 million bbl. The acquired data will allow study of the options for a fast-track development. Geng North-1 was drilled to a depth of 5025 m in 1947-m water depth, encountered a gas column about 50-m thick in a Miocene sandstone reservoir with excellent petrophysical properties. A well production test was successfully performed for a full assessment of the gas discovery and although limited by the test facilities, it has allowed a well capacity estimate of up to 80–100 MMcf/D and up to 6,000 B/D of condensate.
- Asia > Indonesia > East Kalimantan (0.45)
- Asia > Indonesia > Kalimantan (0.32)
Abstract In a standard conventional oil & gas service, each specialized downhole drilling tool service requires dedicated personnel to execute the field operation. This includes but is not limited to measurement while drilling (MWD), logging while drilling (LWD), directional drilling (DD), casing while drilling (CWD), underreaming service, loss circulation management tool service, drill bit performance service, and many others. In a complex drilling bottom hole assembly (BHA) deployment, multiple skilled-personnel presences at the rig site are required which consequently increases the service cost, the personnel safety risk, and the drilling performance risk caused by multiple chains of communication. Additionally, smaller rigs with less person on board (POB) capacity might become a limitation for multiple services to be deployed. From the environmental sustainability perspective, more personnel cause higher carbon emissions from the drilling operation. The Multi-skilling approach for the downhole drilling tool services workforce is the solution for future Oil & Gas operation sustainability. The integration capability of the oilfield service company enables the workforce training matrix to be designed adapting the drilling challenges. The cross-training framework was made available in the forms of base-workshop training checklists, online web-based or virtual instructor-led training, offline courses, and on-the-job training. The multi-skill training pathway for each individual is also tracked and monitored, to ensure all downhole drilling service personnel are equipped with sufficient competency. The multi-skilling was successfully deployed in several projects in Indonesia. A land operation in East Kalimantan executed the DD & MWD operation with fewer personnel by having MWD cross-trained to DD to cover the night shift alone (supported by remote operation), contributing to 25% more personnel-efficient operation. An offshore project in East Kalimantan also completed the drill bit performance service - Directional Drilling – Logging While Drilling – Underreaming While Drilling – Loss Circulation management tool services in an integrated approach with personnel multi-skill, contributed to 42% personnel efficiency by deploying only 4 personnel instead of 7 persons in a conventional way.
- Asia > Indonesia > Kalimantan (0.45)
- Asia > Indonesia > East Kalimantan (0.45)
Full Scale Waterflood Project in Tanjung Field: From Reservoir Studies to Execution
Chaerul Shobar, Muhammad Rully (Pertamina Hulu Indonesia) | Edy, I Ketut Oscar (Pertamina Hulu Indonesia) | Wijaya, Kurnia Agung (Pertamina EP) | Cahaya, Anak Agung Bagus (Pertamina EP) | Aliefan, Tubagus Adam (Pertamina Hulu Indonesia) | Syarif, Purnama Timur (Pertamina EP) | Sihotang, Linggom (Pertamina EP) | Iffah, Aminatul (Pertamina Hulu Indonesia) | Fakhruzan, Ahmad (Pertamina Hulu Indonesia, Currently working for Pertamina Hulu Rokan)
Abstract Tanjung field in Kalimantan at Barito Basin has a long story. It was discovered in 1898 and initially developed few decades later in 1939. Primary recovery had been the main production mechanism until 1995 where peripheric and line-drive water injection begun. By latest cumulative production in 2021, Field Recovery Factor (RF) is still below 25%. This fact of low RF has become attractive subject of study to unlock the remaining oil in place, particularly in Layer A, B, C, and D as the main hydrocarbon accumulation. Therefore, those layers were selected as focus of study in revolutionarily changing peripheric and line drive injection into waterflood patterns. The unlocking initiative was manifested officially in original Plan of Further Development Plan (POFD) issuance in 2015 and revisited later in 2017 as Revised POFD to develop full-scale waterflood implementation with following scope of work: drilling new wells of producers and injector, work-over on existing producer and/or injector wells to establish waterflood pattern, and Water Treatment Injection Plant (WTIP) upgrading. The objective of this paper is to deliver several focuses: (1) Front-to-end workflow of waterflood project from reservoir studies to facilities design, (2) Gap of actual vs design encountered during project execution, and (3) Overcoming the challenges and/or gap in order to achieve target. According to POFD, injection rate was required at 68 kbwipd vs current condition of 40 kbwipd. WTIP upgrade to provide injected water quality on-spec in required quantity is the key driver. In parallel with WTIP upgrade, various workover activities (zone change, perforation, Sucker Rod Pump or ESP replacement, and conversion-to-injector) to establish waterflood pattern while maintaining the field existing production. The main challenge lies on getting the pattern ready as latest as WTIP upgrade completed without disregarding anticipated production loss due to workover on existing producers either shutting-off commingling layers or converted-to-injector (CTI). Moreover, the established patterns were to put in optimization efforts through detailed production and injection performance evaluation to maintain field production target despite not having designated injection rate. Improvised actions also taken as discrepancy between reservoir simulation forecast vs actual performance at pattern level had been encountered. Despite the challenges, all the efforts and actions involving reprioritizing budget, changing well materials procurement, rescheduling injection line replacement timing, rescheduling SRP or ERP delivery, and reallocating injected water from out-pattern into established patterns succeeded contributing incremental production. This paper summarizes lesson learned from actual full field waterflood project: (1) What can go differ from designed requirement in executing a waterflood project, (2) What to anticipate, especially on forecast vs actual pattern performance, (3) How we improvise to overcome gap of reality vs forecast. All the efforts by Pertamina EP successfully slow the decline and boost oil production of Tanjung Field back to level of 2018's in this year.
- Asia > Indonesia > Kalimantan (1.00)
- Asia > Malaysia > Kelantan > South China Sea > Gulf of Thailand (Gulf of Siam) (0.92)
- Energy > Oil & Gas > Upstream (1.00)
- Water & Waste Management > Water Management > Lifecycle > Treatment (0.92)
- Asia > Indonesia > Kalimantan > Barito Basin > Tanjung Field > Tanjung Formation (0.99)
- Asia > China > Heilongjiang > Songliao Basin > Daqing Field > Yian Formation (0.99)
- Asia > China > Heilongjiang > Songliao Basin > Daqing Field > Mingshui Formation (0.99)
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
Laksono, Setiadi (PT Pertamina Hulu Kalimantan Timur) | Palgunadi, Haryotomo Budi (PT Pertamina Hulu Kalimantan Timur) | Aristya, Ramadhana (PT Pertamina Hulu Kalimantan Timur) | Sianturi, Bidner (PT Pertamina Hulu Kalimantan Timur)
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.
- Asia > Indonesia > Kalimantan (0.92)
- Asia > Indonesia > East Kalimantan (0.61)
- Well Drilling > Wellbore Design > Wellbore integrity (1.00)
- Well Drilling > Drilling Operations (1.00)
- Well Drilling > Casing and Cementing > Casing design (1.00)
- (3 more...)
Abstract Deviated drilling is a common cost-cutting strategy used in efforts to develop deepwater hydrocarbon fields. By utilizing the existing platform, new wells are drilled with a particular inclination to reach the intended depth level as a branch of the main vertical well. Drilling at inclination results in a change in the direction of observation from data collection. This change will affect the measured magnitude value when well logging is carried out, especially on physical parameters sensitive to the direction of the measurement such as velocity. Distortion of velocity values due to the orientation effect of data collection has been a limiting factor in seismic analysis because of phase changes during the well-to-seismic tie, inconsistent amplitude variation with offset responses, and ambiguity in the appearance of the hockey stick effect on long-offset seismic data. The oil and gas industry is starting to move toward developing concepts that link the presence of anisotropy recorded in field data with the possibility of hydrocarbon reservoirs. Velocity logging (sonic and shear sonic) should begin to get more attention to support this strategy of making data retrieval results more precise. The motivation of this study is to apply the method of calculating velocity compensation values to reconstruct sonic and shear sonic logs in deviated wells by utilizing anisotropy parameters. By reconstructing the velocity log, the authors attempt to verticalize the log to return the log function to represent subsurface conditions.
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (0.68)
- Geology > Geological Subdiscipline > Geomechanics (0.68)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.30)
- North America > United States > Texas > Haynesville Shale Formation (0.99)
- North America > United States > Louisiana > Haynesville Shale Formation (0.99)
- North America > United States > Arkansas > Haynesville Shale Formation (0.99)
- (3 more...)
A New Approach for Designing an Underbalanced Cementing Plug Using a Managed Pressure Cementing and Pump-Pull Method with Narrow Pore-Frac Pressure Window in HPHT Exploration Well: An Offshore East Kalimantan, Indonesia Case Study
Setiohadi, _ (PERTAMINA) | Hadistira, Praja (PERTAMINA) | Yudhatama, Muhammad Alfianoor (PERTAMINA) | Sitompul, Daniel (PERTAMINA) | Hutabarat, Dhika Escodianto (PERTAMINA) | WIharja, Andre (PERTAMINA) | Panjaitan, Reinhard Aberson (PERTAMINA) | Agriawan, Crisa (PERTAMINA) | Kusumawatie, Reny (Schlumberger) | Wedhaswari, Victoria Rasmi (Schlumberger) | Darmanto, Bagus Setyo (Schlumberger) | Osman, Ahmed (Schlumberger) | Azwar, Cinto (Schlumberger) | Winarti, Wiwin (Schlumberger) | Simanjuntak, Andre (Schlumberger)
Abstract The operator was drilling their first high-pressure high-temperature (HPHT) exploration well with narrow pressure window in a swamp area of East Kalimantan. The gas field was discovered in 1977 and production started in 1990. Since then, more than 1500 wells have been drilled in this area yielding a total gas production of 9.7 Tcf. Currently T field enters established mature field status which has quite marginal reserves. Therefore, further exploration is seen as one of the solutions to locate additional reserves to enhance overall gas production. The well was drilled directionally with no offset well nearby. While drilling the 6-in open hole section, an unexpected high-pressure zone was penetrated. The zone condition was made worse by lost circulation and a high gas reading. Two cement plugs were placed using a managed pressure cementing with pump and pull method. The first plug was set by applying surface back pressure (SBP) to maintain equivalent bottom hole pressure (BHP) between lowermost pore pressure (PP) and fracture gradient (FG) at the previous shoe. After pumping 1 m3 of cement into the annulus, pump and pull operations commenced. While performing post job circulation on the first plug, it was observed that the returned fluid density at surface was less than original mud weight, indicating the possibility of contaminant invasion from formation. After waiting for the cement to reach 500 psi compressive strength, pressure buildup was observed when annulus was shut-in, indicating an inadequate pressure seal across the cement plug Applying lessons learned from setting the first plug, new design considerations were implemented such as increasing cement volume in the annulus to 4 m3 prior to the pump and pull operation to minimize cement overlapping risk and applying SBP at BHP near FG. A contingency plan was in place to determine the appropriate SBP value to be applied whenever the pumping rate was changed. A second plug job was performed safely and flawlessly by achieving the top of cement as desired. A successful inflow test was performed with indication of no contaminant invasion nor pressure bypass around the cement plug. The rig was able to continue its next operation to sidetrack the well. This paper presents the design considerations, methodology applied, and lessons learned two managed pressure cement plugs using pump and pull method in a well bore with a narrow pore-frac window where the new techniques were implemented to enhance success of the plug job despite the complexity and risk inherent with an underbalanced operation.
- Asia > Indonesia > Kalimantan (0.61)
- Asia > Indonesia > East Kalimantan (0.61)
- South America > Chile > Magallanes > Magallanes Basin > Daniel Field (0.93)
- Asia > Indonesia (0.93)
- Well Drilling > Drilling Operations (1.00)
- Well Drilling > Casing and Cementing (1.00)
- Well Drilling > Pressure Management > Underbalanced drilling (0.93)
- (6 more...)
First Implementation of Managed Pressure Drilling (MPD) System in Swamp Barge Rig to Drill Narrow Pressure Window HPHT Exploration Well Safely – Return of Experience from Kalimantan, Indonesia
Setiohadi, _ (Pertamina Hulu Mahakam) | Hadistira, Praja (Pertamina Hulu Mahakam) | Yudhatama, Muhammad Alfianoor (Pertamina Hulu Mahakam) | Sitompul, Daniel (Pertamina Hulu Mahakam) | Hutabarat, Dikha Escodianto (Pertamina Hulu Mahakam) | Wiharja, Andre (Pertamina Hulu Mahakam) | Agriawan, Crisa (Pertamina Hulu Mahakam) | Martadinata, Aji (Apexindo Pratama Duta) | Sudiariaji, _ (Apexindo Pratama Duta) | Sidianto, Agus (Apexindo Pratama Duta) | Prasthio, Andry (Weatherford Indonesia) | Irawan, Fikri (Weatherford Indonesia)
Abstract The first ever HPHT exploration well in Kalimantan was drilled by Swamp Barge Rig with narrow pressure window environment. The well was planned to be drilled using 2.9 SG mud weight to 4575 m vertical depth with 0.10 SG pressure window. Maximum predicted bottom hole temperature of the well was 186° C while the maximum expected wellhead pressure (MEWHP) reached 11,300 Psi. MPD becomes mandatory to complete the well and becomes a novel implement for swamp barge rig operation. Therefore, MPD workshop was held among the teams to ensure all personnel become familiar with the system. On other hand, the equipment configuration was set with some modifications to accommodate the operation requirement, contingency, tight stack up below rotary table and hoisting devices limitation. Rotating Control Device (RCD) was stacked up part by part on tight moon pool space. Several modifications were done properly and gave operation flexibility plus robust contingency. RCD alignment was reset periodically and natural rubbers were utilized to enhanced rubbers lifetime in high temperature condition. EKD system with Coriolis utilization was being main mitigation during drilling with limited kick margin that will allow reservoir section to be accessed. Formation pressure investigation was also performed to give additional information on formation pressure for better well assessment. SBP application on dual gradient tripping and managed pressure cementing give a means to secure the well safely and properly during high gas event with losses condition. As the result, MPD implementation enables the operator to complete HPHT exploration well on swamp barge rig project safely despite the complexity and risk of narrow formation pressure window operation.
Eight inaugural technical series covering production and process engineering topics marked the establishment of the newest SPE student chapter in the archipelago of Indonesia in late 2021. This is part of Institut Teknologi Kalimantan (ITK),which is located on the east coast of Borneo island, expanding its vision and becoming a pipeline to create future industry generations. The inaugural series is a kick-start of the activities in the newly established chapter with a native chemical engineering undergraduate background. A total of 15 speakers and moderators from more than eight companies participated in the technical sessions. The series highlighted topics from drilling fluid technologies, the life cycle of production surface facilities, flow assurance and control, process safety, fracture fluid design, surface well testing, process design, and simulation to petroleum refining process and catalytic cracking.
A Customized High Performance Water-Based Mud Solved the Challenge to Drill Reactive Shale Formation and Simplify the Logistic Challenge in an Exploration Well in Offshore East Kalimantan, Indonesia
Pinartjojo, Djoko (Mubadala Petroleum) | Hutahaean, Edison Tamba Tua (Mubadala Petroleum) | McManus, Ian (Mubadala Petroleum) | Nerwan, Aphrizal S. I. N. (Baroid, Halliburton) | Hansen, Rudiny (Baroid, Halliburton)
Abstract Exploration drilling obviously requires a robust drilling fluid system to be a key factor in overcoming both the known and unexpected challenges of a structure that consists of reactive clay and lost circulation zones. Extra consideration has to be given to regulatory environmental requirements and complications resulting from regional politics. A High-Performance Water Based Mud (HPWBM) system was selected to address the aforementioned issues. The HPWBM was customized to respond to the subsurface conditions with the main requirement to provide maximum shale inhibition through a non-dispersed environment. Polyamine was utilized to stabilize all types of clay; an encapsulation polymer and a non-ionic polymer were included to prevent dispersion and to seal micro-fractures. A complete shale study was performed to determine the optimum concentration of the base fluid and each shale inhibitor. Then hydraulic behaviour of the mud was simulated with contractor proprietary software to understand the parameters for optimal hole cleaning as well as Equivalent Circulating Density (ECD) simulation. The HPWBM system successfully facilitated the execution of the exploration well and provided highly effective clay stabilization. No Non-Productive Time (NPT) was recorded as a result of reactive clay issues. The mud system also facilitated a good rate of penetration (ROP), formation stability, and lubricity. Waste cuttings transportation was not required. In addition, there is also no requirement for costly base oil including its associated transportation costs. The successful implementation of the HPWBM yielded an estimating saving of 25% compared to invert emulsion fluids, prior to considering costs associated with an expensive Liquid Mud Plant (LMP), environmental, and freight costs. Significant cost savings were achieved by eliminating the need for LMP rental, mobilization and demobilization. Another notable saving was realized from the reduced system maintenance of the HPWBM as less dilution was required compared to a regular Water Based Mud. Thinking outside of the box and embracing the departure from the default consideration of an invert system with a thorough risk assessment augmented value to wellbore construction. A smartly designed HPWBM system provided performance comparable to an invert emulsion system but with superior benefits with respect to environmental protection, simplified logistics and lower costs.
- Asia > Indonesia > Kalimantan (0.41)
- Asia > Indonesia > East Kalimantan (0.41)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (1.00)
- Geology > Mineral > Silicate > Phyllosilicate (1.00)