Browsing by Author "Mahbubur Rahman, Dr. Mohammed"

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Analysis of the on stream pigging project of Bakhrabad-Chittagong (175 KM ,24'' DIA) high pressure gas transmission pipeline
(Department of Petroleum and Mineral Resources Engineering (PMRE), 2011-04) Biswas, Ashoke Kumar; Mahbubur Rahman, Dr. Mohammed
The Bakhrabad-Chittagong (BKB-CHT) high pressure gas transmission line was first commissioned in 1983. It is a 175 km long, 24" dia, 960 psig) gas pipeline which was built to supply gas from the Bakhrabad Gas field, Muradnagar, Commilla to Chittagong City Gate Station (CGS), Faujderhat, Chittagong. Gas is being supplied to the consumer of Commilla, Chandpur, Lakhsam, Feni, Maizde, Choumuhoni, Laksmipur, Chittagong as well as the huge area of the South-East part of Bangladesh by the different off-takes along the pipeline. On stream pigging operation was first accomplished to BKB-CHT pipeline in July, 1990 and second time it was done in February, 1994. Significant amount of condensate, sludge and water were recovered from this pipeline during these operations. After thirteen years, on stream pigging operation to BKB-CHT pipeline was done during 12 -13 November, 2007 by Gas Transmission Company Ltd (GTCL). The anticipated amount of condensate, sludge etc. were not recovered from this pipeline during the latest pigging operation. It is therefore necessary to analyse the latest pigging operation to understand the effectiveness, and to find out the reasons for such large differences of the outcomes compared to the previous operations. The investigation reveals that in the beginning years the gas processing at Bakhrabad Gas Field was inadequate. The pipeline was not being used at its full capacity. Due to these reasons, there was scope for accumulation of large amount of condensate. Therefore during the first and second pigging operations, large amounts of condensate were recovered (7,11,000 and 3,87,000 litres respectively). The third (3rd) pigging operation however did not yield the anticipated quantities. The probable reasons are: • After the second pigging operation, BKB Gas Field Process Plant are being operated in sufficient capacity. • In 1997, Ashuganj- Bakhrabad 30˝ pipeline was commissioned. So since 1997, BKB-CHT pipeline have been being operated in actual capacity range. • Since 1997, most of the gas feed to BKB-CHT pipeline was from AB pipeline and this gas was coming from other gas fields such as Titas, Habiganj, Rashidpur, Kailashtila and Jalabad Gas Field. Thus gas from these sources are already processed at origin. Moreover, some liquid is recovered at the Ashuganj Menifold Station. Therefore when the total mix of gas is fed onto BKB-CHT pipeline it is almost dry. • After the second pigging operation, BKB Gas Field, Salda Gas Field and Meghna Gas Field have been supplying dry gas. • Sufficient capacity heater are being used at ICS Feni and CGS Faujderhat after second pigging operation. • During the year 2005-2006, average 3000 gallons/month of condensate were collected at CGS Faujderhat and average 1000 gallons/month of condensate were collected at ICS feni. Therefore it is possible that whatever amount of condensate accumulated in the pipeline were removed during this period. • Since 1997, average 225-250 mmscfd gas was supplied through the BKB-CHT pipeline. So condensate and Sludge could not accumulate inside the pipeline and were collected at ICS feni and CGS Faujderhat. So almost all the condensate were collected after the second pigging operation.
Challenges and remedial measures of well drilling site development in Bangladesh
(Department of Petroleum and Mineral Resources Engineering (PMRE), 2013-10) Shahinur Rahman Farazi, Md.; Mahbubur Rahman, Dr. Mohammed
Drilling activities can take place in diversified geological and geophysical settings, each posing unique type of challenge. There is no universal methodology to address all the situations. Therefore, each project is tailored on a case by case basis. However, it is possible to analyze the problems and to table the common items to bring them under a systematic procedure. Well site development is the initial stage of a drilling project. It involves mainly Civil Engineering works which includes earthworks, leveling, proper compaction, construction of rig and machinery foundation, well site yard, pipe rack, cat walk, mud pit, ware houses, deep water well with water line, office and personnel accommodation, security fencing/wall, sanitary and drainage works etc. An unplanned or faulty development of a drilling site may cause severe problems which may even jeopardize the entire drilling project. State-run and international oil companies have so far drilled about 186 wells in different geographical and geological conditions of Bangladesh. Currently, BAPEX and 4 IOC’s are conducting the country's drilling activities. In onshore, the North-Eastern territory of the country has offered the most of the oil and gas resources. Besides, a number of wells have been drilled in off shore as well. Despite of having the drilling experiences, it is difficult to get a generalized idea on the drilling issues due to lack of compilation of the individual experiences. In this study, the challenges and remedial measures of six representative well sites have been analyzed. This study took a closer look at the challenges and remedial measures of the sites as the first attempt of this kind in Bangladesh. It observed the nature of the problems and their reasons; degree of severity which causes time and cost overrun of a project. For example, the cost overrun comes from 5% to 44% and the time overrun comes from 0% to 83% in the same project due to the severity of the problems such as excessive rain, flood etc. It is revealed that, heavy rainfall during the monsoon and consequent flooding poses the biggest and most common problems for the pre-construction activities before drilling wells. The case-studies showed that the natural constrains caused delay in project implementation, difficulty of logistic movement, raise security issues, damage to equipments and cost overrun. The terrains are either low lands with seasonal water bodies, popularly known as haors, or hilly areas with dense forest. Both types of lands are susceptible to flooding, landslide or washout. Construction and maintaining of the approach road is the next biggest challenge, which is also tied to flooding and remoteness of the location. In some cases, scarcity of manpower and proximity to the international border are also problems. It is therefore important that the weather and flood pattern, availability of manpower and proximity to international border from locations should be taken into account to plan the logistic movement.
Design and analysis of a pipeline system for optimal transmission of natural gas from proposed payra LNG terminal to the southwestern zone of Bangladesh
(Department of Petroleum and Mineral Resources Engineering, BUET, 2022-12-03) Didar Hossain, Mohammad; Mahbubur Rahman, Dr. Mohammed
Bangladesh has set a target to become a high-income country by 2041. Industrialization and job creation are the key factors for its steady growth and development. For industrialization, the country needs a reliable and quality supply of energy at an affordable rate. To achieve its targeted GDP 587,665 million USD by 2041, the country's total energy demand needs to be 130,827 toe. Bangladesh also has a long-term plan to achieve an electricity generation capacity of 40,000 MW by 2030 and 60,000 MW by 2041. At present, 60.44% of the country's electricity is generated by natural gas, and almost 62% of the commercial energy is provided from natural gas. According to current statistics, the remaining natural gas reserve in the country is only 9.3 TCF as of June 2022. It is projected that the daily demand for natural gas in Bangladesh will be approximately 8,346 MMscfd by 2041. If no new major gas discoveries are made, this demand will have to be met by importing Liquefied Natural Gas (LNG). The proposed LNG infrastructure development plans mainly focus on the Chittagong and Cox's Bazaar areas. This will require significant investments in pipelines to transport natural gas to the Southwestern regions of the country. So, to promote the overall economic development of the country, the authorities are aiming to construct a 1,000 MMscfd LNG terminal at Payra, Patuakhali. With the availability of LNG at Payra, it will become necessary to transport LNG to the ultimate consumers in the Southwestern zone. The most economical, easiest, and safest way of continuously transporting such a huge volume of gas is through pipelines. The objective of this research is to evaluate different options for gas transmission facilities that can ensure reliable gas supply to the Southwestern region. To establish a sustainable gas supply infrastructure, a virtual model has been developed to simulate pipeline performance and suggest solutions for future gas demand. The gas network originates from Payra, Patuakhali, and extends downstream to Khulna and Langalbandh. A detailed study is conducted to assess the current demand and supply of gas, future growth forecasts, and existing gas infrastructure in the Southwestern region. After analyzing the gas supply situation with simulation software, it was concluded that 309 km transmission pipeline network, comprising a 42-inch diameter 157 km long Payra-Barisal-Takerhat pipeline and a 36-inch diameter 152 km long Khulna-Gopalganj-Takerhat-Langalbandh pipeline can be constructed to supply gas at the right pressure and quantity to the major load centers in the Southwestern region. Nine alternative scenarios were considered to develop a sustainable gas supply infrastructure and this was deemed to be the best option. After a couple of years, when these pipelines become saturated, installing a 111 km 36-inch Barisal-Jhalkathi-Bagherhat-Khulna pipeline can help overcome the bottleneck of the Southwestern Zone network.
Design of an ideal gas regulating and metering station for gas supply to A 50 MW power plant
(Department of Petroleum and Mineral Resources Engineering (PMRE), 2009-12) Mahbub Hossain, Mohammad; Mahbubur Rahman, Dr. Mohammed
In gas transmission and distribution system, the gas pressure and flow rate are controlled by using CGS, TBS, DRS and RMS. It is important to supply uninterrupted gas at a desired pressure and flow rate to the customer premises. The Regulating and Metering Station (RMS) is generally used for controlling the gas pressure and measuring the gas volume for fiscal purpose. It is apparent that proper design of RMS is very important for a customer for supplying desired amount of gas at a required pressure as well as measuring the supplied gas accurately which is very much crucial for gas supplier in fiscal context. A large number of RMS’s are used for gas supply to different customers in the Titas franchise area. The major objective of this project is to design an ideal gas Regulating and Metering Station for uninterrupted gas supply to a 50 MW power plant. In this project work, fluid characteristics, process data, gas safety rules, International codes and standards (ASTM, ASME ANSI, API) have been followed for the proposed RMS design. Design considerations, selection criteria and installation of RMS equipments are incorporated. Safety and Environmental issues have been considered in designing the gas facilities for the power plant. The negative effects on environment are negligible. The gas load of the power plant is calculated around 12 MMSCFD at minimum outlet pressure of 50 psig. Design has been checked allowing variation of some related variables such as inlet pressure, specific density, specific heat, compressibility factor and heating value. Variation of these parameters needs no change in the design. Instrumentation and piping diagrams of the proposed RMS are also shown in the report. Some recommendations have been made for improvement of the RMS design. Finally, cost estimation is performed for the project. The cost estimation of the project have been calculated on the basis of preconstruction expenditure, construction cost and material cost. The total cost of the project is estimated as Tk. 494.463 Lakh.
Determination of reservoir and well parameters by analyzing the pressure survey and well testing data of Kailashtilla , Biany Bazar and Rashidpur gas fields
(Department of Petroleum and Mineral Resources Engineering (PMRE), 2010-04) Maksudur Rhman, Md.; Mahbubur Rahman, Dr. Mohammed
Well testing provides reliable information about the reservoir and the producing wells that produce from that reservoir. Main reservoir parameters, total permeability-thickness product, kh (md. ft), average permeability, K (md) and initial reservoir pressure, Pi (Psia), and well parameters such as wellborstorage coefficient, C (bbl/psi) and skin, S, are estimated in this project work by using well testing software package (Well Test by Fekete associates Inc.). Data were collected from 8 (eight) wells, 3 (three) of Kailastilla Gas Field, 2 (two) of Biany Bazar Gas Field, 3 (three) of Rasidpur Gas Field, operating under Sylhet Gas Field Limited (SGFL), a company of Petrobangla. Same data are analyzed by Almansoori Wireline Services, a third party welltesting service provider. Intercomp-kanata Management Ltd. (IKM), Oil & Gas Field Exploration Services Company, also determined these reservoir and well parameters under a contract with Petrobangla. The results of the analysis of this project work, AL Mansoori Wireline Services and IKM are shown in a table at the end of the diagnosis of each well. The synthetic pressure and pressure derivative data match with actual pressure and pressure derivative plots, Absolute Open Flow (AOF), coefficient, C, and exponent, n, of the deliverability equation are estimated through this thesis work. The main parameters average permeability, K (md), and skin, S, for KTL#1, KTL#2, KTL#4, BB#1, BB#2, R#1, R#4 and R#7 are 134 and 2.4, 5575 and 4.1, 238 and 9.8, 213 and 17.1, 95.6 and 13.8, 2150 and 7.2, 16 and -4.8, 20.8 and -0.70 respectively. However, from core data analysis; Average Permeability of the Middle Gas Sand, producing zone of KTL#1 and KTL#4, of Kailastilla Gas Field is 88.4 md, and 424.3 md for the Upper Gas Sand, producing zone of KTL#2, of Kailastilla Gas Field, Average Permeability of the Lower Gas Sand, producing zone of BB#1, of Biany Bazar Gas Field is 189.6 md, and 332.4 md for the Upper Gas Sand, producing zone of BB#2, of Biany Bazar Gas Field, and Average Permeability of the Upper Gas Sand, producing zone of R#1, R#4 and R#7, of Rasidpur Gas Field is 370.0 md.
Determination of reservoir properties of a gas field by advanced decline analysis of pressure build-up test
(Department of Petroleum and Mineral Resources Engineering (PMRE), 2013-10) Latifur Rahman, Md.; Mahbubur Rahman, Dr. Mohammed
Estimating reservoir properties has long been a challenge. Traditionally pressure survey or well testing is conducted to estimate the reservoir properties, which is expensive; also production loss is associated with pressure survey. The importance of performing accurate analysis and interpretation of reservoir behavior using only rate and pressure data as a function of time is fundamental to assessing reservoir properties such as permeability, skin and reservoir drainage area. The equations used for well test analysis are derived from the constant terminal rate solution of the radial diffusivity equation (RDE). Conventional Decline Curve Analysis normally used to estimate original gas in place and gas reserves. The development of modern Decline Curve Analysis began in 1944. This technique used to analyze and interpret production data and pressure data from gas wells using Type Curves. This technique is also used to estimate Skin Factor for near wellbore drainage area, Formation Permeability, Reservoir Drainage Area and gas in place. As opposed to well test analysis, the equations used for modern decline analysis attempt to plot rate versus time with different transformations. Therefore theoretically these two independent methods should yield same results. It is of interest to investigate whether in real case two opposite approaches can be used to obtain sufficiently close results of the same properties such as skin, permeability etc. In this study two real cases were analyzed using both well testing and decline analysis. Commercial software Ecrin v4.20 (Saphir and Topaze) was used to carry out this work. It is found that the data quality is the greatest challenge with well testing data is obtained from a relatively short period of time in a controlled environment. If properly done, the data quality is good and results obtained can be reliable. However well testing is done only occasionally in Bangladesh, then developing a good understanding of the reservoir from well testing alone is often difficult. On the other hand decline analysis uses well pressure and production data which is usually available for the entire operational life of a well. Despite the volume of the data it is usually full of noise and difficult to discern the true reservoir signal from the dataset. However, sufficiently close results were obtained from the two approaches. For Well # 4, k was 19.4 from DCA and 25.1 from PBU respectively; S was 0.996 for DCA and 0.64 for PBU. For well A#3, k was 52.53 from DCA and 83 from PBU respectively, S was 1.504 for DCA and 2.97 for PBU. For DCA, two separate techniques (Fetkovich and Blasingame) were applied. They also showed reasonably close estimate of k (15.8 and 18.9) respectably and STGIIP (82.7 and 76.4 bscf).
Enhanced vapor recovery modeling of condensate tank flaring system coupled with existing vapor recovery unit in Bibiyana gas field
(Department of Petroleum and Mineral Resources Engineering (PMRE), 2012-04) Saha, Palash Khanti; Mahbubur Rahman, Dr. Mohammed
The Bibiyana gas field is one of the most prolific gas fields in Bangladesh. It stared production in March, 2007 with 200 MMSCFD. Production has steadily increased from this field, and currently it is producing more than 730 MMSCFD. In addition, Bibiyana field also produces about 3,500 barrels of condensate per day. There are six storage tanks for condensate final stabilization and storage. Significant amount of vapor is produced in these tanks due to shrinkage/flash, standing and working effects. This vapor is hydrocarbon, i.e., natural gas, which has heating value and therefore valuable. There is a three-stage vapor recovery system in the field to capture the vapor produced at different stages of production and processing. However, vapor from the storage tanks cannot be recovered by the existing system because its pressure is too low- nearly atmospheric. It is therefore regularly flared through the Low Pressure Flare line. Flaring of gas is a problem which entails both economical loss and environmental concerns. The hydrocarbon burning produces toxic gases, soot, acid rain, unburned hydrocarbons and a huge amount of CO2, which contributes to greenhouse effect. The economical impact is the cost of gas that is flared. This project demonstrates a method for recovering the low pressure vapor from the condensate tanks. This method uses a Gas ejector as a device to compress the low pressure natural gas from the condensate tanks to an intermediate pressure, which can be fed into the intermediated stage of the existing vapor recovery unit. Thus the natural gas will be saved which would have been otherwise flared. The amount of tank vapor is calculated by different methods, which shows a significant amount of gas which is now being flared. Gas ejector is a device which converts pressure energy of a motive stream into kinetic energy which entrains a secondary stream and discharges the combined stream at an intermediate pressure. This project uses the relatively high pressure gas from the third stage of the existing vapor recovery unit as the motive gas, and the low pressure condensate tank vapor as the suction gas for ejector. The combined discharge stream will be fed into the vapor recovery unit’s second stage.
Experimental study on rheological properties of water based drilling fluid and its impact on drilling operations
(Department of Petroleum and Mineral Resources Engineering (PMRE), BUET, 2024-05-28) Sumon Chowdhury, Md.; Mahbubur Rahman, Dr. Mohammed
Most encountered problems like fluid loss, wellbore stability, well control, poor capacity of cuttings transport, poor torque performance, increased drag, and stuck pipe can occur during drilling due to the improper design of the drilling mud, which can increase the cost of drilling. This study looks into the rheological properties of ten water-based drilling mud and their impact on drilling operations. A viscometer is used to conduct the analysis in the laboratory. The density of the prepared mud ranges from 8.7 ppg to 10.01 ppg. This experimental study focuses on determining the viscosity, gel strength, and yield point of ten water-based drilling mud which are formulated under different barite concentrations. The plastic viscosity of the ten mud samples ranges from 10 cp to 18 cp, yield point ranges from 5 lb/100ft2 to 12.75 lb/100ft2 and gel strength ranges from 2 lb/100ft2 to 9 lb/100ft2. The effect of density on viscosity, gel strength, and yield point is also observed in this study. Key findings indicate that the viscosity, gel strength, and yield point of the drilling fluid are significantly influenced by the density of mud at constant pressure and temperature. Five drilling mud rheological models such as Newtonian, Bingham plastic, Power law, API, and Herschel-Bulkley are analyzed to select the most suitable fluid model and measure the total frictional pressure drop in the wellbore, considering the suitable model. The error analysis of experimental/measured shear stress and theoretical/modeled shear stress is done to choose the most perfect fluid model. The minimum error indicates the best fitted rheological fluid model. This study found the error between experimental/measured shear stress and theoretical/modeled shear stress maximum for Newtonian model (7% to 18%) and minimum for API model (up to 0.16%). The mud samples are preferable for the API model to calculate the standpipe or pump pressure. Data matching is done to compare the experimental and real pressure loss data, SBHP and FBHP. There is good scope in the future to study the effect of some chemical additives on the rheological properties of water based drilling mud in different pressure and temperature.
Feasibility study of gas supply to Rajshahi
(Department of Petroleum & Mineral Resources Engineering, BUET, 2007-12) Sanwar Hossain, Mohammad; Mahbubur Rahman, Dr. Mohammed
The gas fields in Bangladesh discovered so far discovered arc located in the Eastern Part of the country. As a result gas based power plants, fertilizer factories and industries have been set up only in the Eastern Part of the country. Non-availability of natural gas is the major obstacle 10set up industries in the northern region, especially In the divisional city Rajshahi and its adjacent areas. As a result expected development has not been achieved In the northern part. Major objectives of this project arc to study the feasibility of gas pipeline to divisional city Rajshahi which includes design, financial and economic aspects. The study reviews the present gas supply, demand, transmission scenario l\lld also analyzes forecasted production, supply, demand and transmission plan. The study also identifies the limitations of gas supply to divisional city Rajshahi .. Financial parameters such as Net present Value (NPV), Benefit-Cost Ratio (BCR) and Internal Rate of Return (1RR) has been calculated on the hasis of 20 years project life. The analysis is firstly done on the basis of present postage stamp method of wheeling charge. The result of financial analysis shows that NPV, BCR and IRR for base case are Tk. (656.692) million, 0.78 and 13% respectively. The same for pessimistic case are Taka (1690:746) million, 0.43 and 7.65% respectively. For optimistic case these values are Taka 294.611 million, 1.10 and 16% respectively. The result shows that by applying postage stamp method of wheeling charge the project is financially viable only for optimistic case. The result of economic analysis shows that the project is economically viable for base case and optimistic case and not viable for pessimistic ease. On the other hand, if revenue is calculated on distance based wheeling charge then the project is financially viable for base case and optimistic case and economically viable for all cases. Sensitivity analysis shows that the project viability largely depends on the power sector gas demand. With power sector minimum demand the project in not financially viable even with other sectors maximum demand, On the other hand with power sector maximum demand the project is financially viable even with other sectors minimum gas demand.
Reservoir performance analysis of the gas fields of Bangladesh
(Department of Petroleum and Mineral Resources Engineering (PMRE), BUET, 2024-05-28) Nazmul Islam, Md.; Mahbubur Rahman, Dr. Mohammed
Reservoir performance prediction is an iterative process that incorporates various data points, such as production rates, pressure, fluid properties, and geological characteristics. Techniques like decline curve analysis, material balance, and reservoir simulation are commonly used for evaluating a reservoir. The Reserve Performance Indicator (RPI) analyzes parameters such as production rates, pressure data, and fluid properties to evaluate the performance of a reservoir over time. Till now 29 gas fields was discovered in Bangladesh. There isn't any literature or publication that addresses a consistent approach of ranking these reservoirs based on their performance. In this study, an approach is taken to rank the reservoirs according to various indicators used for analyzing the reservoir performance and to identify more prolific and problematic reservoirs. After collecting all the available reports from the public domain (Annual Reports, MIS Reports), reservoirs are ranked by initial reserves, cumulative production (Gas, Condensate), Gas Recovery. The Jalalabad gas field has retrieved more gas than its initial reserve which suggests the necessity of reserve re-estimation. For the majority of discovered fields, the last reserve estimation was completed 14 years ago. Although there is a noticeable reserve in the Kailashtila and Rashidpur fields, just 22.21% and 19.24% of the gas has been recovered, respectively, suggesting that their field development approach is inadequate. Potential gas recovery is possible from these fields. In addition to displaying inadequate development strategies for such fields, only 1 well was drilled in Meghna field during its 26-year production life, while 2 wells were drilled in Narsingdi field over its 27-year production life. Suspended wells of Titas, Habiganj, Bakhrabad, and Kailashtila fields are examined further and the wells of Titas, Bakhrabad, and Kailashtila fields having the potential for workover operation on a priority basis are also identified. Finally, the top 4 fields that are performing well are categorized as Category-I fields, and the 4 fields whose performance was poor and need to change the field development tactics are categorized as Category-II fields.
Reservoir simulation of Haripur gas field to analyze the field performance by production and pressure history matching
(Department of Petroleum and Mineral Resources Engineering (PMRE), 2010-11) Nath, Fatick; Mahbubur Rahman, Dr. Mohammed
Well-7 of Haripur gas field was spud in 1986 by BAPEX. After 07 years of uninterrupted oil production, the well ceased its production on 14th July, 1994. The 1st work over of Sylhet well -7 was completed in March 2005. This well was recompleted in lower Bokabil sand as gas producer with an initial production capacity of 15MMCFD. The gas production was ceased again in July 2008. The 2nd work over has been successfully completed in the existing perforation zone on February 2, 2010. Commercial gas production started from Sylhet-7 with an average production 6-8 MMSCFD with about 2100 psig well head pressure. In this study, material balance, production data analysis (PDA), pressure transient analysis (PTA) and reservoir simulation are conducted to understand the different reservoir information and predict future production performance. This study uses Material balance analysis tool MBAL, Well model software PROSPER, PDA tool TOPAZE, PTA tool SAPHIRE and commercial reservoir simulator CHEARS to find out reservoir characteristics, pressure and production history matching of producing sand of Haripur gas field. This study estimates initial gas in place, recoverable reserves and remaining reserves of producing sand of Haripur gas field. Current study has yielded the gas initial in place of 24 BSCF of lower Bokabil (sand-D) sand which is close to Petrobangla recent study by RPS Energy. Permeability and skin factor of this formation are investigated by pressure transient analysis. No re-estimation of reserve for the other sands is conducted in this study.
Reservoir simulation study of Fenchuganj gas field
(Department of Petroleum and Mineral Resources Engineering (PMRE), 2012-04) Asadullah, MD.; Mahbubur Rahman, Dr. Mohammed
BAPEX operated Fenchuganj Gas Field, 40 kilometer south of Sylhet in Bangladesh, lies in the south central part of Surma basin. A second well FG-2 was spud on January 1985 after the first exploratory well drilled in 1960 was abandoned as dry hole. Three gas sands (Upper, Middle & Lower) were tested and completed the well at upper gas sand in 1988. Gas production from the well started on May 2004. Next a development well, FG-3 was drilled by BAPEX in 2004 and gas production started from January 2005. Gas production from upper gas sand of FG-2 was suspended after extracting 24 BSCF gas due to excessive sand and water production. Later the well was re-completed at lower zone and due to the same reason production rate was lowered. Therefore, future field development plans as well as diagnosis the reason of water break through of the well needs to be investigated. Despite of volumetric analysis, under the project RMP-2 of Petrobangla in 2009, RPS Energy prepared dynamic reservoir simulation model of Fenchuganj Gas Field. In this current study, the geological model was revised by correlating with seismic and log data and imporated in a commercial 3D black oil reservoir simulator ECLIPSETM 100 to construct a dynamic reservoir simulation model. Later the dynamic simulation model was validated by using historical pressure and production rate data in history matching phase. Finally, the history match model was run for five different forecast cases to find out a better field development plan. Forecast Case 5 of the current study yield 81.75% gas recovery out of 386.05 BSCF estimated GIIP after 25 years of prediction period by drilling additional three wells as well as workover of the existing wells. Aquifer support is identified in the upper gas sand during history matching as well as water break through in FG-2 has been investigated.
Study of natural gas processing in Bangladesh
(Department of Petroleum & Mineral Resources Engineering, BUET, 2005-12) Hassanuzzaman Shikder, Muhammed; Mahbubur Rahman, Dr. Mohammed
Natural gas has been an important indigenol.lS hydrocarbon resource in Bangladesh It is predominant fuel for industries and commercial establishments. The natural gas produced from the reservoir is usually a complex mixture of several hydrocarbons in thcir liquid and gaseous states, intimately mixcd with water Often, solids and other contaminants arc also present in the mixturc. Therefore, some processing is fC{luired for the produced natural gas before it can be brought to the customer. The gas processing plants constitute a very important !legment of the gas industry in Bangladesh. Currently, there are six companies involved in producing gas ITom fifteen different gas fields in Bangladesh. These companies operate thirty-nine ga, processing plants, using a variety of technologies. Different technologies are involved in removing different elements ITom natural gas Therefore, a gas processing plant must combine the appropriate technologies to address the needs of a specific gas field. The selection and design of a processing plant i, extremely important for operating a gas ficld efficiently and economically. This study takes a closer look at an these plants in Bangladesh, A scrutiny of each plant is presented with a view to identity potential rooms for improvement. Whereas the knowledge and expertise on one particular plant is available, it is extremely difficult to get a broader perspective of the industry because no comparative literature is available This study attempt> to fill in the knowledge bage by presenting a comparative •• study uf all the plants currently in operation in Bangladesh. It will be beneficial to all partie, interested in the gas processing industry in Bangladesh. It should provide some directives regarding the future of the industry in Bangladesh
Well/reservoir evaluation by using pressure transient and material balance analysis of a gas well in Bangladesh
(Department of Petroleum and Mineral Resources Engineering (PMRE), 2013-10) Hafizur Rahman, Md.; Mahbubur Rahman, Dr. Mohammed
To reach a decision as how best to produce a given reservoir it is essential to know its deliverability, properties, size and initial gas in place (GIIP). Estimating reservoir properties has long been a challenge. Traditionally pressure survey or well testing is conducted to estimate the reservoir properties, which is expensive; also production loss is associated with pressure survey. The equations used for well test analysis are derived from the constant terminal rate solution of the radial diffusivity equation. Well testing data is obtained from a relatively short period of time with a controlled environment. If properly done, the data quality is good and results obtained from this test can be reliable. This technique is used to estimate Skin Factor, Formation Permeability, Reservoir Drainage Area, Average reservoir pressure, distance to faults, Connectivity among well etc. If well testing is done only occasionally, developing a good understanding of the reservoir from well testing alone is often difficult. Conventional Decline Curve Analysis normally used to estimate original gas in place and gas reserves. The development of modern Decline Curve Analysis began in 1944. This technique used to analyze and interpret production data and pressure data from wells using Type Curves. This technique also can estimate skin, permeability and gas in place. But most of the time it is impossible to maintain controlled condition to collect undisturbed data of decline curve analysis for a long period of time like short period of time of well testing data. In this study for a well evaluation real cases was analyzed using both well testing and decline analysis. First Skin and Permeability are determined with the help of pseudo pressure versus Horner time. Also non-Darcy flow coefficient is determined from deliverability test equation. This Skin, Permeability and non-Darcy flow coefficient is a reference point to model a reservoir. Classical material balance and its output GIIP is also another reference point to model a reservoir for modern Decline Curve analysis method The GIIP estimated from classical and flowing material balance methods are 600 BCF and 580 BCF respectively. The same is estimated to be 629 BCF by Fetkovich, 630 BCF by Blassingame and 473 BCF by Arp’s method. Except for Arp’s the rest of the methods provided reasonably close results. The skin factor estimated from well testing analysis is in good agreement with Decline analysis result. Skin, s from Horner plot is 21.15, from type curve is 20, Fetkovich type curve is 19, and Blassingame is also 19. Rate dependent skin is also detected during well test analysis, which was characterized by non-Darcy flow coefficient of 0.456 [MMscf/D]-1. Skin value is quite high, the major contribution is due to formation damage (sd=13) and the partial completion is not significant (sp=2.15). The permeability estimated from well testing is good agreement with past studies. Permeability, k from Horner plot is 201.6 mD and type curve is 236 mD. k was also estimated decline analysis method. Both Fetkovich and Blassingame methods provide ‘k’ value close to each other but order of magnitude lower than well testing results.