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Society of Exploration Geophysicists University of Pembangunan Nasional "Veteran" Yogyakarta (SEG UPN SC) is a container for geophysics students in UPN who want to deploy themselves both soft skills and hard skills. For the sake of broadening the knowledge, our goal is to make the students especially the members to contribute not only in the scope of national level geophysics but also the global level geophysics through the activities such as seminar, workshop, fieldtrip, social activities, course, and many more. SEG SC UPN is under advisory of Mr. Dr. Ir. H. Suharsono MT and had numerous achievements through out the last years. Vision: "To make the SEG UPN SC become a leading organization that synergizes with each other by bringing up a sense of professionalism, good collaboration, and knowledge as geoscientists to face the global competitiveness with critical and creative thinking" College as a part of national education has purpose to develop student to became Indonesian people that has good atitute and academic ability that can applied, improved, and shared to the other. Society of Exploration Geophysicists UPN "Veteran" Yogyakarta are one of organizations that can used to reach the purpose of national education.
- Asia > Indonesia > Yogyakarta > Yogyakarta (0.84)
- Asia > Indonesia > Java > East Java > Bojonegoro Regency (0.71)
- Health & Medicine > Therapeutic Area (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- Materials > Metals & Mining (0.95)
- Asia > Indonesia > Java > East Java > Bojonegoro Regency > East Java Basin > Southwest Java Basin > Cepu Block > Kedung Keris Field (0.99)
- Asia > Indonesia > Java > East Java > Bojonegoro Regency > East Java Basin > Southwest Java Basin > Cepu Block > Jambaran Tiung Biru Field (0.99)
- Asia > Indonesia > Java > East Java > Bojonegoro Regency > East Java Basin > Cepu Block > Banyu Urip Field (0.99)
- Asia > Indonesia > East Java > Sukowati Field (0.99)
- Information Technology > Knowledge Management (0.50)
- Information Technology > Communications > Collaboration (0.40)
Predrill Geomechanical Modelling and Operational Guidance Helped to Successful Horizontal Drilling - A Case Study from Madura Offshore PSC, East Java, Indonesia
Panjaitan, Julianta Parlindungan (Medco Energi E&P Indonesia) | Nurdin, Didin (Medco Energi E&P Indonesia) | Putranto, Heru (Medco Energi E&P Indonesia) | Situmeang, Andy (Medco Energi E&P Indonesia) | Sagita, Romi (Baker Hughes Indonesia) | Chrislianto, Renaldi Mikhael (Baker Hughes Indonesia) | Ghosh, Amitava (Baker Hughes Indonesia)
Abstract A horizontal drilling is considered to be a challenging drilling operation and require a proper pre-assessment study including subsurface, geomechanics and drilling practice. This paper will be taking the case from East Java basin as one of the prolific basins in Indonesia which are hydrocarbon proven with existence of multiple faults. The prospect Meliwis-2 was planned to be drilled horizontally within such heavily faulted regime. The key drilling challenges in the study area are drilling through the overpressure shale sequences and passing through multiple faults in the carbonate reservoir zone. A geomechanical model was built using - limited well data combined with regional geological knowledge. Additional drilling information from other wells from nearby field was also incorporated in this study. Based on the offset well(s) review, some of the key challenges were significant drilling problems which mainly occurred after drilling, such as pack off, tight hole while pulling out of hole (POOH) and problems with running casing and wireline logging. Gain and losses were also observed while flow check and POOH the bottom hole assembly (BHA) in reservoir sections. The model that was built at the offset wells was then applied to perform pre-drill wellbore stability and fault stability of the planned Meliwis-2 horizontal well to optimize the drilling plan and minimize non-productive times related to borehole stability. Then the model was subsequently updated during drilling using the actual drilling and petrophysical information gathered from this new well. The outcomes and recommendations of this study was meticulously followed with the operational guidance by drilling team to complete the well. The well was successfully drilled horizontally with expected data acquisition without any drilling issues due to borehole stability eventhough crossing multiple faults. The well was tested successfully and fulfilled the hydrocarbon expectation. This effort contributed to successful offshore development campaign within tolerance timely execution, budget and no reported HSE events.
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock (0.36)
- Asia > Indonesia > East Java > Java Sea > Madura Offshore Production Sharing Contract > Meliwis Field > Upper Mundu Formation > Meliwis-1 Well (0.99)
- Asia > Indonesia > East Java > Java Sea > Madura Offshore Production Sharing Contract > Meliwis Field > Globigerinid Formation > Meliwis-1 Well (0.99)
- Asia > Indonesia > East Java > Mundu Formation (0.98)
- Well Drilling > Wellbore Design > Wellbore integrity (1.00)
- Well Drilling > Drilling Operations > Directional drilling (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Reservoir geomechanics (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Open hole/cased hole log analysis (1.00)
Abstract High wax content characteristic of Banyu Urip (BU) crude is mitigated by continuous Pour Point Depressant (PPD) injection at multiphase stream. PPD treatment aim to lower Pour Point to 24ยฐC with dosage of 475 ppm. It was observed that PPD dosage started to increase up to 650 ppm. This caused significant incremental cost as PPD accounts for 10% of total field OPEX. This paper shares rigorous troubleshooting method for resolving PPD performance degradation due to higher water cut. To optimize the PPD dosage while ensuring that the wax or crude gelling risk can be well mitigated, following activities were undertaken: [1] Critical parameters data collection and root cause analysis; [2] Formulation of solution to address the root cause; [3] Trial at laboratory scale as the early proof of concept toward the proposed solution; [4] Risk assessment that includes thorough analysis of crude gelling in each pipe section and mitigation required; [5] Field testing and monitoring. As the Banyu Urip field mature, the water cut increases more than double in a year. This condition creates water emulsion that has a detrimental effect on PPD effectiveness. Redistributing PPD injection from multiphase stream at well pad to dry crude stream at inlet export pipeline is deemed necessary to mitigate such issue. Detail review was conducted to assess the risk of reducing PPD dosage at well pad to processing facility especially during unplanned shutdown. Force balance equation was utilized to calculate minimum allowable gel strength in each pipe sections considering different pipe dimension, available pressure in the system, and temperature cool-down profile. Section which has the lowest minimum allowable gel strength and faster cool-down rate was used as governing case for PPD treatment strategy. The lab testing using artificial water emulsion homogenizer also performed to verify PPD effectiveness at different injection stream. This also gives an indication of required dosage and required pump injection capacity for the proposed scenario. The PPD redistribution field testing was then carried out with successful result of 175 ppm (~27%) dosage reduction by leveraging existing facility with fit for purpose approach. This paper provides insights how important the effect of water emulsion should be considered in the design phase, especially to stipulate PPD injection point location. This paper also provides guidance in determining PPD performance criteria using gel strength and pour point test with one-degree interval. Thus, operation strategy to mitigate crude gelling within a processing facility can be carefully developed.
- Asia > Middle East > UAE > Abu Dhabi > Rub' al Khali Basin > Bu Hasa Field > Thamama Group > Shuaiba Formation (0.99)
- Asia > Indonesia > Java > East Java > Bojonegoro Regency > East Java Basin > Cepu Block > Banyu Urip Field (0.99)
Success Story of a Novel Completion Technology of Hybrid ESP-Gas Lift System Trial
Pramana, Harris (Saka Energi Indonesia) | Mario, Cio Cio (Saka Energi Indonesia) | Nugrahanto, Anang (Saka Energi Indonesia) | Hakim, Arief Lukman (Saka Energi Indonesia) | Eviany, Ameria (Saka Energi Indonesia) | Murtani, Anom Seto (Saka Energi Indonesia)
Abstract Selection of the most suitable production technologies; namely the type of lift to be used, to the design and implementation for well conditions has been one main responsibility of petroleum engineers. In an especially limited offshore field, not all methods are applicable as platform spaces, operating costs, and system reliability are needed to be considered. System reliability, for instance, entails well production profile to meet the acceptable operating range and to perform within specific run life to be rendered economic. Ujung Pangkah offshore field, located within Pangkah PSC Block off the northeastern coast of Java Island has been discovered in 1998 and carries on production since 2007. Having a typical gas cap with an oil rim, carbonate reservoir; Ujung Pangkah field has since been developed with commingle completion targeting both separated layers of oil zone and gas zone, utilizing only gas lift as its main artificial lift method. Concern for alternative lifting methods has arisen since 2019, due to the limitation of gas lift injection capacity that is no longer adequate for the current and future development wells at that time. Considering this challenge, Saka Energi Indonesia decided to perform ESP (Electrical Submersible Pump) trial on 2 wells. By design, the proposed completion will be of a hybrid ESP-Gas Lift, possessing both ESP components and typical gas lift components. ESP is decided to be the next artificial lift method to be applied because currently there are unused electric capacities from Gas Turbine Generators. To satisfy the acceptable range of ESP design criteria, both wells are equipped with AGH (Advanced Gas Handler)/Gas Separator, along with a gas vent line to produce this separated gas through the annulus. To fulfill the required dual-barrier-policy in offshore conditions, these wells are using specialized, feed-through-ESP hydraulic packer that enables ESP cable and gas vent line to be passed through. To ensure these wells reach the economic limit of ESP installation, this hybrid completion design is used; utilizing ESP as the main artificial lift and gas lift as a backup so that the well can still be produced with gas lift when ESP experiences failure. On the implementation side, the installation of ESP with backup gas lift on 2 wells has been successfully improving production, each up to 4.5 times and 1.5 times its previous oil rate pre-installation. Despite the first ESP being out of commission, ESP run life has been satisfied and the relative economic limit for the installation has been reached. In addition, the well can still be flowed with a backup gas lift system while waiting for pulling operation, which significantly extends the well run life and overall boosts the well's economic value.
- North America > United States > Texas (0.69)
- Asia > Indonesia > Java > East Java (0.25)
- Asia > Russia > Ural Federal District > Yamalo-Nenets Autonomous Okrug > West Siberian Basin > South Kara/Yamal Basin > Novoportovskoye Field (0.99)
- Asia > Indonesia > Java > East Java > Pangkah PSC > Pangkah Block > Ujung Pangkah Field > Kujung Formation > Tuban Formation (0.99)
- Asia > Indonesia > Java > East Java > Pangkah PSC > Pangkah Block > Ujung Pangkah Field > Kujung Formation > Sidayu Formation (0.99)
- (6 more...)
Pre-Drill Geomechanical Modelling and Wellbore Stability Analysis for Successful Drilling in a Highly Overpressured Shale Zone and Potential Losses Carbonate Zone - A Case Study from West Tuban Block, East Java, Indonesia
Mikhael Chrislianto, Reynaldi (Baker Hughes) | Sagita, Romi (Baker Hughes) | Ghosh, Amitava (Baker Hughes) | Meidiya Putra, Riko (Pertamina Hulu Energi) | Hisanah, Nabilah (Pertamina Hulu Energi)
Abstract A high pressure well with a high risk of encountering a loss zone is a challenging drilling operation and requires a proper pre-drill study incorporating drilling practices, an understanding of the subsurface, and geomechanical modelling. This paper presents a case from the West Tuban Block. This block is within the East Java Basin, one of the prolific basins in Indonesia and a proven hydrocarbon reserve. The major challenge is drilling through the shale overpressure zone and the carbonate loss zone safely and successfully. This paper describes the building of a pre-drill geomechanical model, the subsequent wellbore stability analysis and how the results and recommendations were applied during drilling. The geomechanical model was built using data from seven offset wells and also incorporated regional knowledge. The offset well review of the drilling experiences showed that the key challenges that will need attention are significant drilling problems such as pack-off and tight hole while POOH, RIH with casing and while wireline logging. Added to this are instances of losses and gains while drilling the carbonate reservoir section. The geomechanical modelling process involves using petrophysical, geological, geophysical and drilling data to constrain the magnitudes of the overburden, pore pressure, rock mechanical properties and the two horizontal principal stresses. It is also important to constrain the azimuth of the maximum horizontal stress. The final model is verified using stress-related drilling problems and observations of wellbore failure in shale interpreted from caliper data. The resultant geomechanical model suggests that the planned well is associated with a strike-slip stress regime. The magnitudes and azimuths of the stresses play an important role in successful drilling because the well is directional in the reservoir section with a maximum inclination โผ26ยฐ. The wellbore stability analysis was used to optimise mud weights for each hole section of the planned well. Recommendations were also made regarding additional data gathering (cores for conducting rock tests, extended leak-off tests, full suite of logs, etc.) to reduce uncertainty in the geomechanical model. The mud weight and drilling practice recommendations, that were an outcome of the study, were followed meticulously by the drilling team so the well was able to safely overcome the overpressure zone and the loss zone. The effort contributed to the operator's success in the onshore development campaign with timely execution within budget and no reported HSE events.
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.82)
- Geophysics > Borehole Geophysics (1.00)
- Geophysics > Seismic Surveying > Borehole Seismic Surveying (0.33)
- Europe > Norway > North Sea > Northern North Sea > East Shetland Basin > PL 050 > Block 34/10 > Gullfaks Field > Statfjord Group (0.99)
- Europe > Norway > North Sea > Northern North Sea > East Shetland Basin > PL 050 > Block 34/10 > Gullfaks Field > Lunde Formation (0.99)
- Europe > Norway > North Sea > Northern North Sea > East Shetland Basin > PL 050 > Block 34/10 > Gullfaks Field > Lista Formation (0.99)
- (4 more...)
A New Technology Approach Using Permanent Chemical Tracer for Water Source Identification in Ujung Pangkah Field
Eviany, Ameria (Saka Energi Indonesia) | Mario, Cio Cio (Saka Energi Indonesia) | Hakim, Arief Lukman (Saka Energi Indonesia) | Nugrahanto, Anang (Saka Energi Indonesia) | Pramana, Harris (Saka Energi Indonesia) | Murtani, Anom Seto (Saka Energi Indonesia) | Rashed, Rasha (Resman AS) | Koumouris, Steve (Resman AS) | Huseby, Olaf (Resman AS)
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 โ 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.
- Europe > Norway > North Sea > Central North Sea > Central Graben > PL 018 > Block 2/4 > Greater Ekofisk Field > Ekofisk Field > Tor Formation (0.99)
- Europe > Norway > North Sea > Central North Sea > Central Graben > PL 018 > Block 2/4 > Greater Ekofisk Field > Ekofisk Field > Ekofisk Formation (0.99)
- Asia > Indonesia > Java > East Java > Pangkah PSC > Pangkah Block > Ujung Pangkah Field > Kujung Formation > Tuban Formation (0.99)
- (7 more...)
CO2 Huff and Puff Injection Operation Overview in Jatibarang Field Lessons Learned from a Successful Case Study in Mature Oil Field
Halinda, D. (PT Pertamina, Persero) | Zariat, A. Az (PT Pertamina EP) | Muraza, O. (PT Pertamina, Persero) | Marteighianti, M. (PT Pertamina, Persero) | Setyawan, W. (PT Pertamina, Persero) | Haribowo, A. (PT Pertamina EP) | Rajab, M. (PT Pertamina EP) | Firmansyah, M. (PT Pertamina EP) | Hasan, I. (PT Pertamina EP) | Nurlia, D. (PT Pertamina EP) | Adham, A. (PT Pertamina EP) | Prabowo, P. (PT Pertamina EP) | Okabe, H. (JOGMEC) | Mikami, K. (JOGMEC) | Kento, K. (JOGMEC) | Susanta, P. (NESR Indonesia) | Palupi, A. S. (NESR Indonesia)
Abstract The objective of this paper is to provide an overview of the CO2 Huff and Puff injection operation in the mature Jatibarang field, Indonesia, and share the lessons learned from a successful case study. The scope of this paper includes the project preparation, implementation, and troubleshooting. The aim is to provide insights into the key factors that contributed to the success of the project and to identify potential challenges and their solutions. The paper will present a comprehensive review of the CO2 Huff and Puff injection process, start from the design of the injection plan and the monitoring and evaluation of the injection process. The methods, procedures, and process used in the project will be discussed, including the selection of candidate wells, the injectivity test, the CO2 injection rate, and the well performance evaluation. The paper will also highlight the challenges faced during the implementation of the project and the solutions adopted. The results of the CO2 Huff and Puff injection operation in the Jatibarang field are promising, with an oil production rate increase of up to 86% with minimum operational difficulties. The successful implementation of CO2 Huff and Puff injection operation in Jatibarang Field was mainly attributed to the good operation procedure that prioritized safety and efficiency. With careful planning and intensive discussion conducted to identify potential risks and minimize operational difficulties, the operation was able to run smoothly, with minimal issues and zero HSE incidents. One of the key challenges that CO2 injection operations usually face is the risk of pipe blockage due to CO2 freezing. Fortunately, no such incidents occurred during the operation. Continuous monitoring of the injection process and fluid properties managed to ensure that the CO2 remained in gas phase in surface and supercritical state in the bottom hole throughout the operation. In conclusion, the success of the CO2 Huff and Puff injection operation in Jatibarang Field was due to the careful preparation and execution of a well-designed operation procedure. The operation demonstrated that with the right approach, the potential risks and challenges associated with the project can be mitigated. This paper will present novel information on the implementation of CO2 Huff and Puff injection in a mature oil field in Indonesia. The lessons learned and the best practices identified in this project can be of benefit to the petroleum industry, particularly for those dealing with mature oil fields. The paper will also provide insights into the design of the injection plan and the monitoring and evaluation of the injection process, which can be useful for future CO2 Huff and Puff injection projects.
- Asia > Indonesia > Java > Subang Field (0.99)
- Asia > Indonesia > Java > Northwest Java Basin > Jatibarang Field > Talang Akar Formation (0.99)
- Reservoir Description and Dynamics > Storage Reservoir Engineering > CO2 capture and sequestration (1.00)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery > Thermal methods (1.00)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery > Chemical flooding methods (1.00)
- (2 more...)
Retrievable Socket Electronic Memory Recorder as a New Method of Bottom Hole Pressure and Temperature Survey in a Mature Field
Azhim, Luthfan Nur (PT Pertamina Hulu Rokan Zona 4) | Pratama, Satria (PT Pertamina Hulu Rokan Zona 4) | Aryawan, I Gusti Ngurah (PT Pertamina Hulu Rokan Zona 4) | Pranata, Angga (PT Pertamina Hulu Rokan Zona 4) | Renaldo, Wan (PT Pertamina Hulu Rokan Zona 4) | Aullia, Diandra (PT Pertamina Hulu Rokan Zona 4) | Wibawa, Agung (PT Pertamina Hulu Rokan Zona 4) | Mulyanagara, Guntur (PT Pertamina Hulu Rokan Zona 4) | Kuncoro, Anang Arie (PT Pertamina Hulu Rokan Zona 4)
Abstract This paper presents valuable new method from Pertamina Hulu Rokan Zona 4 in bottom hole pressure and temperature (BHPT) survey. Nowadays, the conventional method and gradient pressure acquisition is only able to be done by using slickline after swabbing job, because during swabbing job, the swabbing tool string is used inside the tubing. Unfortunately, there are missing data when influx from reservoir occurred, due to the shut-in condition may not always represent overall characteristic of well. Retrievable Socket Electronic Memory Recorder (Retrisock EMR) is consisted of seating parts with deliverable and retrievable mechanisms. Engineering design was done to ensure it compatible for acquiring data during swabbing job without slickline unit. Retrisock EMR is put inside tubing, it is possible to record data since run in hole tubing, pressure test packer, swabbing job, pressure build up and static gradient pressure temperature. It could be retrieved without pull out tubing from well to download the data, nevertheless, the data may be uncertain for further analysis. The advantage, it could be put back into tubing by using sand line rig. Pressure and temperature were obtained during swabbing job represent the influx from reservoir into well. The graph of pressure can be approached as a well test, such as modified isochronal test which can be processed to pressure transient analysis for further determination of skin value, reservoir boundary and permeability. Combination of fluid total volume during swabbing job and pressure transient analysis result become reference whether well stimulation is needed or not, before putting on production well. Result of static gradient pressure analysis will estimate the static fluid level also could be used as measured gradient of fluid in well for calculating inflow performance relationship (IPR) precisely. The result of implementation in Talang Akar Formation, Benakat Barat Structure, well BKB-272 increased production significantly from 600 BFPD to 800 BFPD after evaluated by using data from Retrisock EMR measurement. Two more promising benefits of Retrisock EMR are time and cost efficiency. Based on study and implementation, it can reduce operation time up to 10 hours. Then, the impact of faster operation time is less operation cost Tool and method presented in this paper provide valuable concept for well optimization in developing BHPT survey before and after stimulation to compare the reservoir influx without pull out tubing string and slickline. Another opportunity is BHPT survey without shut in the well in oil well producer while it on production by using artificial lift electric submersible pump (ESP) that was not equipped with downhole sensor as real time monitoring tool.
- Asia > Indonesia > Sumatra > Pendopo Field (0.99)
- Asia > Indonesia > Java > Northwest Java Basin > Talang Akar Formation (0.99)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Well performance, inflow performance (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Drillstem/well testing (1.00)
- Production and Well Operations > Well Intervention (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring (1.00)
- Information Technology > Architecture > Real Time Systems (0.54)
- Information Technology > Data Science > Data Quality (0.48)
Integration of High-Definition Karst Mapping and Quantitative Porosity Analysis from Borehole Image to Improve Well Placement in Complex Carbonate Reservoir of East Java Basin
Azwar, Olivia (Schlumberger Oilfield Services) | Permanasari, Dian (Schlumberger Oilfield Services) | Ardikani, Nadia (Schlumberger Oilfield Services) | Adani, Nabilah (Schlumberger Oilfield Services) | Kusuma, Didit (PETRONAS Carigali Indonesia Opns) | Abrar, Budi (PETRONAS Carigali Indonesia Opns) | Nordin, Taufik (PETRONAS Carigali Sdn Bhd) | Widianto, Tonny Fadjar (PETRONAS Carigali Indonesia Opns) | Priyanka, Elvara (PETRONAS Carigali Indonesia Opns) | Roosa, Figa (PETRONAS Carigali Indonesia Opns) | Soenarwi, Isra Febrianto (PETRONAS Carigali Indonesia Opns)
Abstract The CD Carbonate in X-Field, East Java Basin has multiple reservoir targets with varying flow units, predominantly because of secondary porosity development from karst processes. Each of these reservoirs are relatively thin and the continuity of the karst within the reservoir is random. The amount of producible hydrocarbon will rest on the length of the drain section along the reservoir and the amount of karst intersected by the trajectory. Thus, maintaining the trajectory inside the carbonate reservoir while targeting the karst position is important for productivity. To maintain the production in the field, a new platform was built to the southeast of the first platform, aiming for a new development area. Five horizontal wells were planned as part of the second development phase. The first horizontal well is the most challenging one because of the high uncertainty of the structural dips along the lateral length triggered by the low seismic resolution and the limited nearby offset wells for control points. Moreover, the offset wells show inconsistent log properties that complicate the correlation to land into the targeted karst level within the reservoir. Initially, a pilot hole was planned to reduce the landing uncertainties; however, it was being challenged for cost efficiency. Therefore, a well placement strategy was proposed instead, including landing and geosteering using a new logging-while-drilling (LWD) combination of advanced high-definition reservoir mapping technology, high-resolution laterolog borehole imaging technology, and a multifunction LWD tool. In this paper we demonstrate the complete preparation of the well placement project, strategy, and evaluation using this new LWD combination for better interpretation of the reservoir. The deeper reading and higher resolution of the new reservoir mapping technology have permitted continuous mapping of the target reservoir, which typically has 35- to 50-ft thickness, to reduce the structural uncertainties from seismic. For the first time, it successfully revealed the karst network within the reservoir with greater details, identified by a blue-vein color spectrum of the resistivity inversion caused by seawater invasion or clay-filled karst. This high-definition karst mapping has helped to land the well precisely at the target karst sweet spot, improving the understanding of the karst characters along the trajectory, and providing higher confidence in the real-time geosteering decision. The high-resolution borehole image revealed the carbonate rock texture and karst/vugs appearance on a smaller scale, which was used to analyze the secondary porosity distribution and contribution along the trajectory using a quantitative image-based porosity analysis method. By integrating the high-definition reservoir mapping inversion interpretation and porosity analysis from a high-resolution borehole image, we were able to bridge the gap from seismic to reservoir scale, and finally to link the karst scale down to the vug pore sizes, for a better geological understanding and an improved geosteering strategy in the field.
- Phanerozoic > Cenozoic > Paleogene (0.69)
- Phanerozoic > Cenozoic > Neogene (0.47)
- Geophysics > Seismic Surveying > Borehole Seismic Surveying (1.00)
- Geophysics > Borehole Geophysics (1.00)
- Oceania > Australia > Victoria > Bass Strait > Gippsland Basin (0.99)
- North America > United States > Texas > Permian Basin > Yeso Formation (0.99)
- North America > United States > Texas > Permian Basin > Yates Formation (0.99)
- (24 more...)
Abstract The gas injection system at Banyu Urip oil production facility in Indonesia consists of two compressor trains. Each train comprises one LP and one HP centrifugal compressor with a gas dehydration system in between. In 2020, one dehydration system experienced fouling and subsequently increased the gas moisture content. The condition initiated corrosion product formation flowing to both the LP and HP compressors of the particular train and subsequently damaged the compressor Dry Gas Seal (DGS) system. The paper will be focusing on the investigation of two dry gas seal failure cases due to contaminated process gas by corrosion product. The corrosion product blocked the seal gas strainer of HP compressor and caused reverse flow across the labyrinths seal, exposing the dry gas seal to dirty gas. Additionally, as the process gas coming into the LP compressor has not been dehydrated, field inspections revealed the second failure case that the process gas condensation caused accumulation of the fine debris at the orifice plate of the seal gas leakage line. Various improvements and dry gas seal system modifications were carried out to cope with the dry gas seal failures, such as the installation of duplex seal gas strainer to allow strainer replacement without shutting down the compressor. Furthermore, the Electrical Heat Tracing (EHT) installation at the seal orifice plate also successfully prevented the process gas condensation. Upon implementation of the strategies, the Banyu Urip facility successfully managed to improve the reliability of the gas injection system despite fouling gas dehydration unit.