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Riau
Managing Safety Risk and Oil Spill During Pre-Breakthrough Steam Flood by Steam Early Detection with Artificial Intelligent
Triananda, Ade Hamzah (PT. Pertamina Hulu Rokan) | Aji, Muhamad (PT. Pertamina Hulu Rokan) | Wibawa, Ramdhan Ari (PT. Pertamina Hulu Rokan) | Silaban, Meita (PT. Pertamina Hulu Rokan) | Pasaribu, Rinaldi (PT. Pertamina Hulu Rokan) | Rifani, Ria Ayu (PT. Pertamina Hulu Rokan)
Abstract Delta Area-X is the newest steam flood project in Delta Heavy Oil Field in Riau Province of Sumatra, Indonesia. The area currently produces 12,000 BOPD from 450 oil producers and 145 steam injectors that are supported by high proactive optimization that consists of steam cyclic stimulation, chemical stimulation, and pump optimization. The steam flood life cycle is divided into three general phases: immature phase, transition/steam breakthrough phase, and mature phase. Delta Area-X is currently entering the transition period. The transition phase is the most challenging period because steam has broken through for some producers. Many producer failures experiencing sanding problems, holes in pipes, rapid production changes, scale problems, etc. These are the challenges to completely heat the project area. At this period, the team is supposed to maintain and continue steam injection, conduct cyclic steam in cold producers to connect steam zones, and mitigate steam breakthrough impact on producers by building a fluid level and pinch casing valve. Steam rate reduction in this phase may delay heating area. Delta Area-X has experienced several steam breakthroughs events that caused the production casing line to be cut out and cause oil spills. To prevent similar cases, similar events should be identified earlier to know which wells, where and when for later on leading preventive actions. Identification started by integrating data from surveillance data from field such as artificial lift, field operation pressure and temperature survey and production performance trend. Artificial intelligence was introduced to the identification process by pattern recognition artificial lift surveillance data to determine indication of steam. The result of Artificial Intelligence combines with dynamic well condition drives condition to meet: gradually detection and sudden detection to oil producer. Since there are many wells operated in the area, an exception signal is required to alert engineers only on wells that has potential issues. Since application of steam breakthrough signal, the team can quickly make recommendations to manage steam by installing chokes, size up casing choke, reduce stroke per minute (SPM), reduce stroke length (SL) or the most massive action: shut in well oil producer / steam injector. Managing the steam will help controlling the steam causing casing cut out or oil spill and in term of steam flood management, it will redistribute steam to other wells or redirecting steam growth in order to have good sweep efficiency. Since the implementation of this approach, the team has identified more than hundred wells that were captured by steam breakthrough signals, then it followed up with appropriate action that successfully prevented potential safety hazard.
Low Cost Alternate Solution to Produce the Shallowest Productive Low-Quality Reservoir in WK Rokan
Afif Ikhsani, Muhammad (PT. Pertamina Hulu Rokan) | Putra, Azarico (PT. Pertamina Hulu Rokan) | Rafi, Muhammad (PT. Pertamina Hulu Rokan) | Alfajrian, _ (PT. Pertamina Hulu Rokan) | Barezzi, Muhammad (PT. Pertamina Hulu Rokan) | Jati, Nugroho (PT. Pertamina Hulu Rokan) | Sunjaya, Rizky (PT. Pertamina Hulu Rokan)
Abstract Low Quality Reservoir in WK Rokan is quite famous as a large volume of remaining recoverable resource, where TLS Formation owned the biggest share (~51%) of the total Low-Quality Reservoir potential additional reserves. This formation develop widely in Central Sumatra Basin with range ~600 ft TVDSS depth and the deepest productive reservoir in ~4000 ft TVDSS. The 600ft TVDSS TLS Reservoir is identified as the most challenging Low-Quality Reservoir in term of its subsurface and operation since this formation has been producing for decades. This Reservoir located in BLSO field in Riau Province, Central Sumatra, Indonesia approximately 140 km Northwest of Pekanbaru or 50 km northwest of the DRI field. The field is a large elongated anticlinal structure bounded on the southwest by a major high-angle reverse fault. The shallowest productive TLS in WK Rokan has a minimum recovery factor with a low reservoir quality which has permeability range of 20-300 MD due to the thin overburden barrier (shallow structure), reservoir complexity (low reservoir permeability, low sand connectivity) that led to limitation of completion strategy resulted in low oil recovery. It is found in 1972, and commercially produced as an oil-producing well with a reservoir depth of 800 - 1000 ft TVD with current recovery factor only 8%. The drive mechanism in this reservoir is shown as a weak water drive reservoir. The old-fashioned development strategy from this shallow low-quality reservoir is by having hydraulic fracturing with cased hole completion which will be driven a high-cost development scenario if we want to increase oil recovery in this reservoir. The alternate solution in developing this shallow reservoir is by optimizing productive section interface, and Open Hole Screen Liner is coming out as solution with lower investment to add more recovery with average production 49 BOPD and low average water cut (51%). This paper will talk about in how we develop well candidacy to apply open hole screen liner completion method, the result and future development plan to improve oil recovery in shallowest low quality reservoir in WK Rokan.
- Asia > Indonesia > Sumatra > South Sumatra Basin > South Sumatra Basin > Telisa Formation (0.99)
- Asia > Indonesia > Sumatra > Central Sumatra Basin (0.99)
Comparison of Surfactant-Polymer and Polymer Flooding in a High Temperature Sandstone Reservoir
Masduki, Agus (P.T. Chevron Pacific Indonesia) | Syafwan, Muhammad (P.T. Chevron Pacific Indonesia) | Nursyahid, Bambang (P.T. Chevron Pacific Indonesia) | Armpriester, Andrew (Chevron Project Resources Company) | Dean, Robert (Ultimate EOR Inc., Formerly Chevron ETC) | Dwarakanath, Varadarajan (Chevron North America Exploration and Production) | Malik, Taimur (Chevron Energy Technology Company) | Meaux, Dwight (Saudi Arabian Chevron Inc.) | Slaughter, Will (Chevron Energy Technology Company) | Thach, Sophany (Chevron Energy Technology Company)
Abstract Results from two field trials designated as Minas Surfactant Field Trial 2 (SFT2) and Polymer Field Trial (PFT) are presented. Quantitative tracer interpretations were used to estimate sweep and displacement efficiency and confirm the performance of both SFT2 and PFT. The pilot patterns in both SFT2 and PFT consisted of a central producer surrounded by six chemical injectors and further confined by six hydraulic control wells that injected water alone. In order to make quantitative comparisons, both the surfactant-polymer and polymer pilots were run at the same mobility ratios to understand if incremental recovery was a function of improved volumetric sweep or increased displacement sweep efficiency. The results of the two pilots show that at the same well spacing and mobility ratio, incremental sweep is very similar and significantly higher than pre-chemical waterfloods. An important finding of the tracer tests is that water injectors should not be used to confine chemical injectors as the water tends to bypass the higher viscosity polymer chase and potentially disrupts the oil-bank. The results from the pilots indicate that for a mature, waterflooded reservoir, surfactant-polymer flooding was preferable as it lowered the final remaining oil saturation and increased oil recovery. Polymer flooding mainly accelerated oil recovery by recovering additional oil from unswept zones and had minimal impact in a mature reservoir. Interwell tracer technology combined with moment analyses were used to make quantitative comparisons of both processes and allowed for several technical insights. This is the first time in literature that a quantitative comparison of surfactant-polymer flooding and polymer flooding alone has been presented.
- Europe (1.00)
- Asia > Indonesia > Riau (0.28)
- North America > United States > Texas (0.28)
- Europe > United Kingdom > North Sea > Central North Sea > Moray Firth > Moray Firth Basin > Block 13/22a > Captain Field > Captain Formation (0.99)
- Europe > France > Chateaurenard Field (0.99)
- Europe > Austria > Vienna Basin > Matzen Field (0.99)
- (5 more...)
Revisiting EOR Projects in Indonesia through Integrated Study: EOR Screening, Predictive Model, and Optimisation
Hartono, A. D. (Kyushu University) | Hakiki, F.. (King Abdullah University of Science and Technology) | Syihab, Z.. (Institut Teknologi Bandung) | Ambia, F.. (SKK Migas) | Yasutra, A.. (Institut Teknologi Bandung) | Sutopo, S.. (Institut Teknologi Bandung) | Efendi, M.. (Pertamina Upstream Technology Center) | Sitompul, V.. (Pertamina Upstream Technology Center) | Primasari, I.. (Pertamina Upstream Technology Center) | Apriandi, R.. (Pertamina Upstream Technology Center)
Abstract EOR preliminary analysis is pivotal to be performed at early stage of assessment in order to elucidate EOR feasibility. This study proposes an in-depth analysis toolkit for EOR preliminary evaluation. The toolkit incorporates EOR screening, predictive, economic, risk analysis and optimisation modules. The screening module introduces algorithms which assimilates statistical and engineering notions into consideration. The United States Department of Energy (U.S. DOE) predictive models were implemented in the predictive module. The economic module is available to assess project attractiveness, while Monte Carlo Simulation is applied to quantify risk and uncertainty of the evaluated project. Optimization scenario of EOR practice can be evaluated using the optimisation module, in which stochastic methods of Genetic Algorithms (GA), Particle Swarm Optimization (PSO) and Evolutionary Strategy (ES) were applied in the algorithms. The modules were combined into an integrated package of EOR preliminary assessment. Finally, we utilised the toolkit to evaluate several Indonesian oil fields for EOR evaluation (past projects) and feasibility (future projects). The attempt was able to update the previous consideration regarding EOR attractiveness and open new opportunity for EOR implementation in Indonesia.
- North America > United States (1.00)
- Asia > Indonesia > Sumatra (0.47)
- Asia > Indonesia > Riau (0.30)
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > North America Government > United States Government (0.88)
- Asia > Indonesia > Sumatra > Riau > Central Sumatra Basin > Rokan Block > Rokan Block > Minas Field (0.99)
- Asia > Indonesia > Sumatra > Central Sumatra Basin (0.99)
- Asia > Indonesia > Sumatra > South Sumatra > South Sumatra Basin > Rokan Block > Rokan Block > Duri Field (0.93)
- (3 more...)
Low Resistivity Oil Sands: CO and PLT Logs Find By-passed Oil and Extend Life of Mature wells
Faizal, Ardi W (Energi Mega Persada) | Handoyo, Tri (Energi Mega Persada) | Panca, Suci W (Energi Mega Persada) | Pramudhita, Bayu Adhi (Energi Mega Persada) | Jafet, Jafet (Energi Mega Persada) | Mudayana, Riko (Schlumberger)
Abstract This is a case history of how aggressive well surveillance can increase oil recovery and dramatically extend well life. MSBK is a 20 MMSTB OOIP field in the Malacca Stait PSC, located on Padang Island, Riau Province, Sumatra (Figure-1). Oil has been drained from the Lower Sihapas G-3010 sand in two development wells: MSBK-1 for 22 years, and MSBK-2 for 13 years. Other sands were penetrated, but had low-resistivity or 2-3 ohm.m, which was similar to water sands and shale. Given this lack of resistivity contrast, these sands were not considered further. By 2011, oil production had declined and was approaching the economic limit. Facing the prospect of abandoning the wells, the team looked at ways to extend well life. Although the resistivity logs were not promising, oil shows were noted in the G-1010 and G-1020 sands in MSBK-2, with other oil shows in the G-1010, G-1015 and upper G-3010 sands in MSBK-1. This paper will elaborate the workflow used to find potential by-passed oil, covering wireline and mud logs, through-tubing perforation (TTP), surveillance logs and finally the workovers. The team successfully found and developed the by-passed oil. MSBK-2 had an oil gain of 150 Bopd, and the workover paid off in 12 days. MSBK-1 had oil gain 135 Bopd, and the workover paid off in 27 days.
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.58)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (0.50)
- Asia > Indonesia > Sumatra > South Sumatra Basin > South Sumatra Basin > Telisa Formation (0.94)
- Asia > Indonesia > Sumatra > Riau > Central Sumatra Basin > Rokan Block > Menggala Formation (0.94)
- Asia > Indonesia > Sumatra > Central Sumatra Basin > Petani Formation (0.94)
Abstract As a Production-Sharing Contractor to BP MIGAS (Indonesian Government Body for Oil and Gas), PT Chevron Pacific Indonesia (CPI) - Chevron Sumatera Operations is Indonesia's largest oil producer. CPI employs approximately 6,500 people and additional 30,000 people as contractors in its operating area throughout Riau Province on the island of Sumatera. The huge numbers of facilities around 800 are operated in CPI. It is believed that there several hazards during job activity. In managing those hazards, CPI initiated to deployed FSWP - Fundamental Safe Work Practices system since 2003. There are seven elements: Access Control, Work Permit, Personal Protective Equipment, Standard Operation Procedure/Job Safety Analysis, Lock-Out & Tag Out, Material Safety Data Sheet, and Housekeeping. Each element consists of: definition, scope, process, infrastructure, and specific competency on process performers. One of Process performer is Facility Owner who is a leader that has a role to assess his assigned facility in monthly basis. FAsT is an IT Application to track and trace the last status of FSWP implementation in every facility inside CPI. This Application is intranet using network database. The users are: Data inputer, Facility Owner, General User, and administrator. Using this local web-based application is effective to see how far the FSWP implementation in all CPI facilities. Every employee has an access to generate report on the facility. Introduction Job activities in Oil and Gas industry related to several hazards such as hydrocarbon, radioactive, explosive material, temperature, mechanical, electrical, chemical, etc. If there is an interaction with hazards then the probability of accident occur will be high. Prevention to accident is managing hazards by elimination, substitution, engineering design, administrative, and using personal protective equipment. Elimination and substitution are not applied for hydrocarbon in oil and gas industry. If those happened, it means no business in oil and gas. The engineering design and personal protective equipment also have some limitations. The most applicable is administrative approach in handling hazards. The administrative approach includes policy, procedure, standards, codes, etc. PT Chevron Pacific Indonesia (CPI) applied the Fundamental Safe Work Practice (FSWP) process to manage hazards. In 2003, the FSWP initiative started consists of seven elements: access control, work permit, personal protective equipment, standard operating procedure/job safety analysis, lock-out and tag-out, material safety data sheet, and housekeeping. Those elements shall be applied in all facilities. To ensure implementation on FSWP, there is a monthly self assessment. The self assessment conducted by facility owner of the facility. Each assessment record and documentation related to FSWP shall be managed well by facility owner. To track any records on the assessment, in 2007, another initiative comes out to create web-based application as database. The application called as FAsT - FSWP Assessment Tracking; consists of all seven elements assessment, recommendation, and action item as needed.
Abstract Kotabatak field, Sumatra, Indonesia is a heavily-faulted field undergoing an aggressive drilling and development campaign. Nine horizontal wells had been drilled with four more planned in 2008. One of the horizontal wells recently experienced well collapse (and sudden productivity decline) after some time on production, with cavings being flushed out during coil tubing workover operations. In addition to horizontal well drilling, feasibility of open horizontal well completions, hydraulic fracturing design and sanding onset prediction also warranted rock mechanics analyses. To make sound decisions on those issues, building a well-calibrated geomechanical model was critical. In this study, we reviewed the drilling, completion, logging and production information from several wells across the field. We found that (1) The Kotabatak field has a general maximum horizontal stress orientation of NESW. However, there could be localized stress orientation variations depending on structure complexity near a specific well. (2) There was no consistent evidence indicating a significant contrast between the maximum and minimum horizontal stresses. Using a maximum/minimum horizontal stress ratio of 1.05 yielded a consistent calibration result for the wells studied. (3) Sand minimum horizontal stress for the Kotabatak field was calibrated against available closure stresses from hydraulic fracturing and mini-frac data. (4) Rock mechanical properties were calculated with openhole logs based on a Rock Mechanics Algorithm that is closely linked to Chevron's worldwide rock mechanical property database. Consequently, even though there were no core test data available from the Kotabatak field to calibrate rock mechanical properties directly, the log data set provided the means to estimate reliable formation mechanical property values that are consistent with Chevron's worldwide database. Furthermore the entire geomechanical model was calibrated against offset drilling performance measures resulting in a high degree of confidence in the predicted values. Using the calibrated geomechanical model, horizontal well stability predictions were performed and indicated that horizontal sections can be drilled with low mud weight allowing the well to have some yield/failure. Open horizontal well sanding onset prediction indicated that the depth and width of a breakout (or plastic zone if reservoir sand behaves plastically) increase with increasing pressure drawdown. Since water flooding is used in the field to maintain reservoir pressure, sand control may not be needed if an appropriate Bottomhole Flowing Pressure (BHFP) is applied. Introduction The Kotabatak field, Sumatra, Indonesia is a heavily faulted field undergoing an aggressive drilling and development campaign ((Figures 1 and 2). Nine horizontal wells had been drilled (as of the end of 2007) with four more planned in 2008. One of the horizontal wells recently experienced well collapse (and sudden productivity decline) after some time on production, with cavings being flushed out during coil tubing workover operations. In addition to horizontal well drilling, feasibility of open horizontal well completions, hydraulic fracturing design and sanding onset prediction also warranted rock mechanics analyses. To make sound decisions on those issues, building a well-calibrated geomechanical model was critical.
- Asia > Indonesia > Riau Province (1.00)
- Asia > Indonesia > Riau (1.00)
- North America > United States > Montana > Rosebud County (0.45)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock (0.48)
- Geology > Structural Geology > Tectonics > Plate Tectonics > Earthquake (0.46)
- Geophysics > Seismic Surveying (1.00)
- Geophysics > Borehole Geophysics (1.00)
- Asia > Indonesia > Sumatra > Riau > Central Sumatra Basin > Rokan Block > Rokan Block > Kotabatak Field (0.99)
- Africa > Angola > South Atlantic Ocean > Lower Congo Basin > Area B > Block 0 > Greater Vanza Longui Area (GVLA) Field > Pinda Formation (0.99)
Abstract An integrated geological study has been performed for a large, mature field at the Bekasap and Menggala formation. The primary goal of the study was to developed an integrated reservoir description for targeted infill drilling and improve recovery in a low-permeability reservoir. Integration of geological and petrophysical studies and reservoir performance analysis provided a rapid and effective method for developing a comprehensive reservoir description. A 3D geocelluar model of reservoir architecture and properties distribution was made and used as a guide to further development. This model delineates distinct trends of estuarine, sand ridge, and margin facies throughout the field that reflect paleogeography. Additionally, reservoir properties and saturations were geostatistically populated within the model. Horizontal wells were chosen as the preferred alternative to provide maximum exposure of reservoir layers and improve production and ultimate recovery compared to conventional vertical wells or frac jobs. Thirty one (31) horizontal wells were drilled in the Bekasap field, and this program was very successful and predicted ultimate recovery has improved from 14% to 28%. The study of this low permeability reservoir in the Bekasap field is an excellent opportunity to:demonstrate the economic importance of this zones, understand the methodologies required for identifying and evaluating these pay types, and help the company to find additional reserves in the Central Sumatra Basin. Introduction The Bekasap field is located at Sumatera Island, approximately 120 km north of Pekanbaru city, Indonesia, within Rokan Block Production Sharing Contract of PT. Chevron Pacific Indonesia (Fig-1). This field was discovered in June 1955, and put on production in September 1957, currently consisting of 107 producing wells, 16 injection wells, 12 P&A wells, and 2 disposal wells. Due to the long period of its production, most of the main reservoirs have shown pressure depletion. To augment the reservoir pressure and increase the oil production rate, the main reservoirs / high quality sands have been peripherally water flooded starting July 1997. The oil at the high quality sands that is referred to clean sands have been swept mostly by existing vertical wells, while low quality sands is refer to shally sands that have poor permeability but still quite potential in producing some oil contained in the sands. Cased hole resistivity has been run in several wells to identify the remaining oil left Following to the success of the pilot horizontal well Bekasap#103 in the low permeability reservoir, thirty one (31) horizontal was drilled. The targets of horizontal wells were 1950'Sand of Bekasap Formation and upper 2420' Sand of Menggala Formation. Generally, this program was very successful and delivered attractive improvement of ultimate recovery. However, several horizontal wells were recognized delivering oil below prediction due to any reason such as well placement, effective lateral length, drilling execution, and completion.
- Geology > Geological Subdiscipline > Stratigraphy (0.69)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock (0.47)
- Geology > Sedimentary Geology > Depositional Environment > Transitional Environment (0.36)
- Asia > Indonesia > Sumatra > South Sumatra Basin > Rokan Block > Rokan Block (0.99)
- Asia > Indonesia > Sumatra > Riau > Central Sumatra Basin > Rokan Block > Rokan Block > Bekasap Field > Menggala Formation (0.99)
- Asia > Indonesia > Sumatra > Riau > Central Sumatra Basin > Rokan Block > Rokan Block > Bekasap Field > Bekasap Formation (0.99)
- (5 more...)
Abstract Environmental liabilities for an onshore oil field include facility abandonment, well plug and abandonment, environmental investigation and remediation, and land restoration. Having a systematic approach for discharging these liabilities offers prudent fiscal management and business planning, environmental compliance assurance, improvement of company image, minimization of legal claims, and ability to secure resources to implement work. In 2003, Chevron began to develop a strategy to manage the liability associated with their CPI Sumatra Operations. The first step was to understand the magnitude of the liability by conducting a Liability Inventory. Next, the liabilities were prioritized based on safety, environmental, security, and operational considerations. Cost estimates were completed and an annual plan developed to discharge the liabilities over a selected time period. For larger remediation projects, decision and risk analysis was employed to determine the preferred timing for execution accounting for the time value of money, likelihood of incidents and the consequences if those incidents occurred. Management of liability for facility abandonment also involves asset write off so that integration of this financial process is required. Technologies and procedures were developed for implementation, focusing on safety and cost effectiveness through standardization. Methods were developed for management of wastes generated which included liquid hydrocarbon wastes, contaminated soils, insulation waste, scrap equipment and piping, and concrete foundations. Management of environmental liability is an evergreen process. At CPI, we have found that review is necessary twice per year to keep up with all the changes due to new information from environmental site assessments, schedule adjustments usually due to resource limitations, and priority changes due to public pressure or claims. The paper will describe the strategy, processes, and methods in more detail. This approach may be applied at almost any on-plot facility or off-plot well field to plan for management of liability. Nature of Liabilities Chevron Pacific Indonesia (CPI) Sumatra Operations operates oil fields north of Pekanbaru to produce Sumatra Light Crude in many small remote oil fields and Heavy Oil from the Duri Steam Flood Field. When oil fields reach peak production is the time to manage environmental liabilities. In 1995, the Duri Steam Flood in Sumatra, Indonesia reached peak performance of 280,000 BPOD heavy oil. In 2006 the field produced 2 billion barrels since May 1958. CPI continues to expand the number of production and injection wells to alleviate the production decline but many wells and surface facilities have also been shut down. The costs of discharging all the environmental liabilities for a field of this size are considerable, so that it is prudent to begin while the field is still generating sufficient revenue to cover these costs. Facilities The types of facilities to be abandoned include:Central Gathering Stations Steam Generation Stations Well Test Stations Casing Vapor Collection Stations Pumps and Wellhead equipment Fuel Filling Stations Piping Failure to properly abandon these facilities may create the following problems:Re-use of the equipment as spare parts for operating facilities Theft of the equipment from unsecured locations Safety incidents due to unauthorized entry by the public Oil spills to the surrounding environment caused by leaks from equipment due to corrosion or tampering by unauthorized persons
- Asia > Indonesia > Sumatra (0.86)
- Asia > Middle East > Qatar > Arabian Gulf (0.24)
- Asia > Indonesia > Riau > Pekanbaru (0.24)
Crude Oil Contaminated Soil Clean Up With Bioremediation: A Case Study and Implementations in Minas Field, Indonesia
Rumbiyanti, Endah (PT Caltex Pacific Indonesia) | Hermiani, Fani (PT Caltex Pacific Indonesia) | Aji, Budi Susilo (PT Caltex Pacific Indonesia) | Nugraha, Sapta (PT Caltex Pacific Indonesia)
Abstract PT. Caltex Pacific Indonesia (CPI) is strongly committed to maintaining a clean environment for nearby communities while providing safe and healthy working conditions for its workers and business partners.While operational standards and regulations have improved since operations began in 1952, a variety of incidents over the years have caused soil in some of the surrounding areas to be contaminated with crude oil.CPI is applying bioremediation techniques to mitigate this impact. Bioremediation is a batch process utilizing microbial digestion of hydrocarbons to clean up soil contaminated with crude oil.Bioremediation land farming was selected because it is a cost effective method, it complies with Government of Indonesia (GOI) regulatory requirements and it is a technology with proven success for producing an end product which is safe to be utilized for re-vegetation and landfill within certain restrictions for areas within Minas Field.The process involves excavation of the soil, hauling the material to Soil Bioremediation Facilities (SBFs) where it is spread and processed (land farmed) by tilling (aeration), irrigated, fertilized with nutrients (fertilizer), monitored regularly by analyzing soil samples for Total Petroleum Hydrocarbon (TPH). Once the TPH meets levels within acceptable concentrations stated in GOI regulation, the soil is removed from the sites and redistributed in predetermined areas based on specific criteria. The averagecycle time of this complete process is 5 months. In CPI's Minas field alone, 5 bioremediation sites are operated continuously providingfor a processing capacity of 45,000 cubic meters of soil per year resulting in approximately 150,000 m3 of soil being processed between 1997 to today.During this time CPI made great strides in improving the process through creating more sites, trying different equipment and operating methods. However, CPI continues to seek new innovations and research to increase efficiency, reduce overall cycle time and increase capacity. Introduction In 1994, PT Caltex Pacific Indonesia committed to discontinue using crude oil in various applications. Since then, research on bioremediation technology application to treat Minas oil contaminated soil was initiated. Feasibility study on biodegradation of Minas crude was started by applying laboratory-scale test. Minas crude characteristic with 34º API gravity led biodegradation through an easier process. The pilot test was applied afterward as the lab-scale test was declared success. The biodegradability of a crude oil is the single most important parameter in determining success or failure of a bioremediation project. The molecular weight and structure of hydrocarbon compounds affects their biodegradability, and the composition of oils is reflected in their API gravity. Therefore, API gravity can be used as a rough predictor of the biodegradability of crude oils.Crude oils having API gravities of >30º are usually readily biodegraded and it is suitable for bioremediation. Considering Minas topography, soil characteristic and its contaminated area condition, Ex-situ Landfarming Bioremediation was considered as the best method to be applied. It was implemented in field-scale in 1997. Two treatment facilities were prepared with the purpose of trying two types of microorganisms used for degrading the crude oil. The same treatment was applied at both facilities but the type of microorganism was different. One used indigenous microorganism while the other used exogenous microorganism. The result indicated both had same good performances. For that reason, it was decided to continue using indigenous microorganism as no additional cost needed to get a good result.
- Asia > Indonesia > Riau (0.93)
- Asia > Indonesia > Riau Province (0.83)
- Energy > Oil & Gas > Upstream (1.00)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (0.94)