The SPE has split the former "Management & Information" technical discipline into two new technical discplines:
- Data Science & Engineering Analytics
The SPE has split the former "Management & Information" technical discipline into two new technical discplines:
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Laya, Krishna Pratama (JOB Pertamina Medco E&P Tomori Sulawesi) | Helbet, Ricky (JOB Pertamina Medco E&P Tomori Sulawesi) | Purba, Victor Stephen (JOB Pertamina Medco E&P Tomori Sulawesi) | Sagita, Romi (Baker Hughes) | Chrislianto, Reynaldi Mikhael (Baker Hughes) | Younessi, Ahmadreza (Baker Hughes)
Abstract The challenge of drilling in relatively frontier area with active collision margin typical of Eastern Indonesian foreland basins requires an integrated geomechanics analysis to identify drilling hazards, improve well design, and optimize drilling cost. Earlier batch drilling located in the northern part of the Senoro Field targeting on pinnacle carbonates did not encounter significant drilling issue, except for minor tight spots and losses in the carbonate reservoir section. However, later drilling batch in the southern part of the field which associated with large strike-slip faulted platform carbonates encountered significant drilling issues related with pack-off, tight hole, and stuck pipes while tripping in 5000 ft long 12-¼” hole section within the Kintom Formation overburden, despite of initial high penetration rate. In order to identify and prevent similar drilling issues, 1D Wellbore Stability Analysis (WBS) workflow conducted to solve the vertical stress and pore pressure, elastic rock properties, horizontal stresses around the wellbore. Fault stability analysis (FSA) conducted to understand the possibility of fault reactivation due to drilling activity. In addition, lessons-learned from drilling experience and best-practice improvement in offset well is also evaluated to validate with the geomechanics analysis results. Introduction The uniqueness and importance of K-shaped Sulawesi island is long recognized as one of the most tectonically active area in the world where plate collision occurred and has been major interest for research in fields of academic and E&P industry. Recent oil and gas discoveries and multiple potential exploration play in the East Sulawesi area has resulted several prominent mid- to large-sized gas condensate fields, which prompted exploration and development drilling activities since the early 2000’s (Barmi, 2003; Hasanusi, 2004). This trend shows the development of oil and gas field will be increasingly important operation in the area (Fig.1 location map)
Dotoku, Shun (PT.MCXASIA) | Hutagalung, Danny Riau (JOB Pertamina-Medco E&P Tomori Sulawesi) | Purba, Victor Stephen (JOB Pertamina-Medco E&P Tomori Sulawesi) | Jailani, Djunaedi Tugiman (JOB Pertamina-Medco E&P Tomori Sulawesi)
Abstract Trapped gas saturation is existing gas saturation after displacement by water and it is one of the key parameters for the estimation of gas recovery factor and gas production deliverability for the reservoir, especially gas reservoir under active water drive. This paper presents a case study of producing North Senoro gas field in Indonesia for series of experimental work of trapped gas saturation measurement and comparison with estimated trapped gas saturation using well-known correlation from various core experiments results. Effect of trapped gas saturation on gas recovery and gas production deliverability were also assessed in various sensitivity analysis using simulation model. Trapped gas saturation varies with rock physical properties such as rock type, porosity, permeability and initial gas saturation and experiments method. Various core samples were chosen to cover range of rock properties in bulk of reservoir and we applied two experiment methods under spontaneous imbibition, Counter-Current Imbibition (CCI) and Co-Current Imbibition (COI). Measured trapped gas saturation had strongly dependency on permeability rather than porosity. The comparison between two methods illustrated that COI showed lower trapped gas saturation compared to CCI except the core plug with high permeability. Difference of measurement results between CCI and COI came from different boundary condition and flow regime between air and toluene during experiment. As co-currently flow regime by COI was closer to fluid behavior in reservoir condition compared to counter current flow regime by CCI, the results from COI was adopted for further analysis. Both of CCI and COI results showed higher trapped gas saturation compared estimated one from Agarwal correlation which defined trapped gas saturation as a function of rock type, porosity, permeability and initial gas saturation. It indicated measurements for specific formation is necessary and critical, especially for complex carbonate formation instead of using correlation. The measured data was utilized to analyze effect on recovery factor in North Senoro gas field as a case study. In simulation model, trapped gas saturation was defined as a function of permeability and initial gas saturation based on our experiment results and Land equation. Sensitivity analysis results concluded that effect of trapped gas saturation on gas recovery factor was limited without any aquifer drive meanwhile trapped gas saturation was critical under strong aquifer support because bulk of gas was trapped by water under high pressure and it kept abandonment pressure high at the end of production high. In addition to accurate measurement of trapped gas saturation, clear understanding of aquifer strength is necessary for realistic gas recovery factor estimation and optimum development planning.
Abstract North Senoro Gas Field is located onshore at Sulawesi Island, operated by JOB PERTAMINA – Medco E&P Tomori Sulawesi. The aim of North Senoro Project Development is to produce gas from limestone reservoir (Mentawa reef) which has unique characteristic formation that total loss hazard wasn't found at the adjacent well. One of effort to solve the problems is bullheading. In this paper, it will explain how bullheading might become a sufficient method for controling pressure during stripping operation while curing loss circulation problem. Well control situation in sandstone and carbonate formation has different characteristic. In carbonate, well control issue is mostly come by total loss which caused the mud hydrostatic pressure was less in the wellbore. Curing loss circulation was the first major to control pressure on the well. Also on sandstone formation, has more compact if hasn't fault or fracture on there. The well control issue happened in 8-1/2? hole section; the situation occurred when suddenly got total loss in the bore hole. It was followed by the increasing number of background gas from the cutting. Shut in well, got record of SICP is 1700 psi and SIDP is 0 psi. The operations continued with circulate gas out through choke simultaneously with original mud and LCM to try plugged the loss zone and filled up the hole. The result was same with no indication of curing the loss problem. Decided to circulate on the two side, through annulus and inside drill string, while circulate mud and LCM through drill pipe got plugged. The engineer team made some analysis then created few scenarios, such as severing BHA, perforate drill pipe to make communication with annulus, continued pumping mud and LCM via annulus (bullheading), or stripping operation. With all assumptions and condition, the stripping operation while bullheading became the best choice to POOH BHA and running OE to cure loss circulation with BDOP/BDOC, then continue with circulate out gas/kick. Finally, with 2 spot BDOC and the last BDOC was modified using LCM to mitigate micro fracture in cement, loss circulation solved then following circulate out gas by driller method. For total loss and kick issue, the important thing that we have to assure is pressure gradient and availability of water and LCM material. Setting casing shoe at the high rating pressure will give us much possibility to select the way of curing loss circulation and kick. RIH OE pipe and spot BDOP & BDOC through OE pipe became success story to curing the loss for next well. Finally, the safety for crew, environment and production target is achieved with this option at North Senoro Gas Field.
Hadinata, Dwie (JOB Pertamina - Medco E&P Tomori Sulawesi) | Mansur, Deutra (JOB Pertamina - Medco E&P Tomori Sulawesi) | Rahmadona, Desmawati (JOB Pertamina - Medco E&P Tomori Sulawesi)
Abstract North Senoro Gas Field is located onshore, operated by JOB PERTAMINA – Medco E&P Tomori Sulawesi. The aim of North Senoro Development is to produce gas from limestone reservoir (Mentawa reef), member of Minahaki formation to fulfill gas supply commitment to Donggi Senoro LNG Plant. First spud of drilling operations was on 16 September 2013 at "well F". One of the drilled formations in Senoro Field is Kintom formation, which is dominated by quite reactive clay with sandstone insertion and limestone. Some swelling clay related problems has been quite often encountered when exploration wells drilling took place. It was also backed up by the CEC (Cation Exchange Capacity) test data done on cutting from Kintom formation, which gave the value of 20 meq/100g. However, the well-sites for upcoming wells are surrounded by people and rice paddy field, making environment impact is a critical point in drilling mud selection. Therefore, by assessing all those critical expected requirements out of the drilling mud, it was decided to use High Performance Water Base mud system to drill Kintom formation. Various water-based drilling fluid type with various type of chemical for clay inhibition were assessed. However, the mud was expected to also have a very minimum Chloride content. This value should be very low that it should not have a significant impact on surrounding environment. From selection and laboratorium process, the approved shale inhibitor on this mud system was Ultrahib. The Ultrahib inhibitor is a liquid additive that acts as a clay hydration suppressant by intercalating and reducing the space between clay platelets so that water molecules will not penetrate and cause shale swelling. This paper will cover, from planning phase to operational phase, how Ultrahib performed and how an optimized concentration of Ultrahib that was adjusted along the way, could overcome the challenge of clay.
Panhar, Muhammad Lutfi (JOB Pertamina – Medco E&P Tomori Sulawesi) | Rahmadona, Desmawati (JOB Pertamina – Medco E&P Tomori Sulawesi)
Abstract In September 2013, North Senoro development drilling of JOB PERTAMINA – Medco E&P Tomori Sulawesi operated Senoro Field – Central Sulawesi, Indonesia commenced when the rig was rigged up over a rig base in Well B Cluster with 8 new well slots available. The well slots were the 20" conductors, piled when the project was still in site preparation phase. Drilling commenced with objectives of drilling, completing and testing 6 new directional wells and 1 re-entry wells. The objective of the Field development was to have high gas production rates available when JOB PERTAMINA – Medco E&P Tomori central processing facility and Donggi Senoro LNG Plant was completed and started in first week of January 2015. Since all wells had to be drilled before first production, and require few weeks to connect the wells with central processing facility then all effort was addressed to optimized operation, shortening operation time and avoid any incident or accident. Walker Rig and Batch Drilling System were implemented to fulfill the entire objective and minimize costs. The Batch Drilling System was applied based by the availability of designated well slots in Well B Cluster. These well slots position were placed based on planned operation which expected to complete 4 first wells (Batch Group 1) and do well testing while at the same time, the rig was moved to the other side of 3 remaining wells (Batch Group 2) and drill the wells. In planning this system, all risk had to be considered when performing simultaneous operation of drilling and well testing (SIMOP); including when there was well control situation since North Senoro Field is a gas field with total loss reservoir and 2,900 psi reservoir pressure. By utilizing Walker Rig and Batch Drilling System, JOB Pertamina – Medco E&P Tomori Sulawesi has been able to save moving days from 56 days to actual 15.56 days, saving at least +/− USD 1.3M and achieve HSE performance 1,923,683 man hours without loss time.
Abstract This paper will be discussing about drilling operation of the Matindok Gas Development Project (MGDP) of PT Pertamina-EP that was developed in order that the gas consumptions of Eastern Indonesia territorial could be well fulfilled. Lost circulation & kick problem with major content of H2S and CO2 that were potentially expected to be drilling hazard at Manahaki formation of the field, therefore it would be a great challenge to be discussed on this paper. Matindok Field had been developed since the POD (Plan of Development) was approved in year 2008 after this Matindok gas field was discovered with predicted IGIP of 347 BCFG. There were totally 7 delineation/development wells that were drilled under MGD Project. The latest well (Well #8) was completed and tested with the results of 10.671 MMSCFD, 149.99 BCPD from Menahaki Formation and 20.23 MMSCFD from the other previous completed well (Well #6). Since to drill the Matindok wells have consisted of several drilling hazard (such as, shallow gas, lost zone and high pressure zone) therefore the drilling program of the wells required a thorough preparation on drilling engineering (i.e studies and evaluations) before PT. Pertamina-EP able to prepare all the matter concern with the execution of drilling operations. Lesson learned that was encountered on the earliest wells that were drilled had been evaluated in order eliminated all potential drawbacks as experienced, Therefore drilling performances can be improved. Detail operational drawbacks and evaluations process to results significant drilling performance improvement from one wells to other consecutive wells will be discussed in detail on this paper. Drilling cost of the Well #6 indicated significant improvement had been well achieved. Drilling Division of PT Pertamina-EP had spent only around 66 % of the approved AFE budget of the well to complete the well and zero non-productive time (NPT) record was achieved when drilling the well (Well #8).
Hasanusi, Deddy (JOB Pertamina-Medco Energi Tomori Sulawesi) | Wijaya, Rahmat (JOB Pertamina-Medco Energi Tomori Sulawesi) | Herawati, Neni (JOB Pertamina-Medco Energi Tomori Sulawesi)
Ophiolite Belt as shown on Figure 1. Senoro gas field is located within the Senoro-Toili Block in the eastern arm of Central Sulawesi, Indonesia and is operated by JOB Pertamina-Medco E&P Tomori Sulawesi. Three principal play types are present in the Senoro-Toili Block area, consisting of Miocene Carbonate Reef Buildup, Wrench Fault Anticline and ImbricateThrust Sheet Anticline structures. Potential reservoir of Senoro field is provided by Miocene carbonates of Minahaki Formation including the Mantawa Member reefal carbonates facies, which contain excellent porosity and permeability. Figure 1 Banggai Basin Regional Tectonic Setting Image Perm technique presents the results of integrating the sedimentological descriptions of The Banggai-Sula micro-continent has been interpreted conventional cores and petrophysical analysis with the as a fragment of the major Australia-New Guinea interpretation of borehole images and conventional continental plate, which itself had been formed during logs. Electrical borehole images combined with a full the Mesozoic break-up of Gondwanaland. Following suite of the open hole logs, offer powerful means of the break-up, the Banggai-Sula micro-continent drifted characterizing facies and pore space. Characterization westerly, directed by the South Sula-Sorong Fault. As of porosity and flow units in a carbonate reservoir is the micro-continent continued its westward drift, an achieved using the method of linking rock fabric aerially extensive Miocene carbonate shelf with descriptions and petrophysical properties as proposed in localized reef growth was developed along the microcontinent Jennings -Lucia model (2003).
Abstract Senoro gas field is located geologically in a tectonically complex area of the eastern arm of Sulawesi, Indonesia formed by a collision process between the Banggai-Sula micro-continent and the East Sulawesi Ophiolite Belt. The primary reservoir objective is a carbonate complex of Miocene age which consists of the Mantawa reefal Buildup facies member and Bioclastics Platform facies of Minahaki Formation. The lateral distribution of carbonate facies can be delineated to optimize a favorable location for field development. In this paper we present the results of integrating the sedimentological descriptions of conventional cores with the interpretation of borehole images, conventional logs, and seismic acoustic impedance in order to identify the facies in the reservoirs not being cored. The technique in combining the electrical borehole images with a full suite of the open hole logs, core data and seismic acoustic impedance which offer powerful means of characterizing lateral facies and pore space distribution as it is confirmed by the 6th well drilled in the field.
China is regarded as a reliable customer for oil because of soaring local demand, but in recent years, it has also emerged as a global operator and provider of services. Although the country is one of the world's largest energy consumers as a whole, it is considered a small consumer per capita and coal remains the main source of energy. In 2012, coal accounted for 70% of China's energy use. At a panel session during OTC, Yan Cunzhang, president of China National Petroleum Corporation's (CNPC) foreign development department, said that energy consumption per capita in China will continue to rise. National companies such as CNPC will continue to play a leading role in China's petroleum industry, even as the country moves away from subsidizing energy-related products, he said.
Suwono, Sugiyanto Bin (JOB Pertamina Medco E&P Tomori Sulawesi) | Wijaya, Rahmat (JOB Pertamina Medco E&P Tomori Sulawesi) | Masbudi, Herryadi (JOB Pertamina Medco E&P Tomori Sulawesi) | Muttaqin, Muttaqin (JOB Pertamina Medco E&P Tomori Sulawesi) | Prasetyo, Hadi (SKKMIGAS)
Abstract Based on current approved development plan of Senoro gas field, the field will be produced at rate 300 MMSCFD (net) to fulfill the gas demand. Existing study based on black oil reservoir simulation conducted on developing depletion plan of Senoro Field give an unexpected result of plateau time which is only 11.7 years while the field has gas delivery contract for 13 years. This possibility of shortfall gas tends to risk the company to get a penalty as termed in the contract. Further analysis of the existing development plan also shows that the gas depletion plan is not yet optimal. It is indicated by the unbalance recovery factor between southern and northern reservoir area as it is shown by a significant difference of its reservoir pressure at the end of contract year. Furthermore, the design of production network planned for Senoro Field also indicating huge pressure losses will be encountered by the southern area wells. To solve the problem, a new study has been conducted to optimize the development plan. The method used in this study is dynamic coupling simulation by connecting reservoir simulation and surface network system into a single package of simulation run. This study has successfully optimized the Senoro field depletion plan to achieve the target 13 years of plateau time. Strategies used to achieve the target are by rescheduling well, utilizing pressure booster in southern area, installing gas compressor after 9th years of production, introducing horizontal well S-22hw to substitute well S-22, and reducing the number of well to 19 from the original plan of 21 wells.