Nádrže s tenkým okrajem se obvykle týkají nádrží s platovou tloušťkou menší než 100 stop. Těžba ropy z těchto nádrží představuje problémy především kvůli přítomnosti plynového uzávěru a vodonosné vrstvy, stejně jako umístění vrtů vzhledem ke kontaktům kapaliny. . Dynamika plynového uzávěru a vodonosné vrstvy ovlivňují produkci ropy a pečlivé umístění vrtu je nezbytné pro optimalizaci obnovy a minimalizaci vlivu těchto faktorů. Tento projekt si klade za cíl předpovědět produkční výkonnost horizontálního vrtu v tenkém ropném ráfku pomocí simulátoru Eclipse. K dosažení tohoto cíle byl vytvořen model tenkého olejového ráfku pomocí simulačního softwaru ECLIPSE. Bylo simulováno a analyzováno několik scénářů zahrnujících různé injekční tekutiny, délku horizontálního vrtu, typy vrtů a strategie umístění vrtu. Tyto scénáře byly porovnány se základním případem, aby se vyhodnotila kumulativní produkce ropy, vody a plynu. Zjištění odhalují, že prodloužení délky horizontálního vrtu z 1800 stop na 2700 stop zvyšuje produkci ropy o 17,5 % (z 2745440.5 na 3225610.8 stb). Vstřikování vody horizontálními vrty vykazuje nejvyšší produkci ropy (2786540.8 stb) ve srovnání s vertikálními vrty. Vstřikování plynu dvěma vertikálními vrty však přináší dalších 20 % produkce ropy. Simulační studie navíc ukazuje, že nejúčinnější umístění vrtu nastává v hloubce 36 stop pod kontaktem plyn-olej (GOC) a 26 stop nad kontaktem voda-olej (WOC), což vede k maximální produkci ropy 2920763.5 stb. ve srovnání s jinými scénáři.
Anotace v angličtině
Thin oil rim reservoirs typically refer to reservoirs with a pay thickness of less than 100 ft. Extracting oil from these reservoirs presents challenges primarily due to the presence of a gas cap and aquifer, as well as the positioning of wells in relation to the fluid contacts. The gas cap and aquifer dynamics affect oil production, and careful well placement is essential to optimize recovery and minimize the influence of these factors. This project aims to predict the production performance of a horizontal well in a thin oil rim reservoir using Eclipse simulator. To achieve this objective, a thin oil rim model was created using the ECLIPSE simulation software. Multiple scenarios involving various injection fluids, length of horizontal well, types of wells, and well placement strategies were simulated and analyzed. These scenarios were compared against a base case to evaluate the cumulative production of oil, water, and gas. The findings reveal that extending the length of the horizontal well from 1800 ft to 2700 ft enhances oil production by 17.5% (from 2,745,440.5 to 3,225,610.8 stb). Water injection through horizontal wells exhibits the highest oil production (2,786,540.8 stb) compared to vertical wells. However, gas injection through two vertical wells yields an additional 20% of oil production. Moreover, the simulation study indicates that the most effective well placement occurs at a depth of 36 ft below the gas-oil contact (GOC) and 26 ft above the water-oil contact (WOC), resulting in a maximum oil production of 2,920,763.5 stb compared to other scenarios.
Klíčová slova
Klíčová slova: Okrajový zásobník ropy, horizontální vrt, vstřikování vody a plynu, umístění vrtu
Klíčová slova v angličtině
Keywords: Oil rim reservoir, horizontal well, Water and gas injection, well placement
Rozsah průvodní práce
53 pages
Jazyk
AN
Anotace
Nádrže s tenkým okrajem se obvykle týkají nádrží s platovou tloušťkou menší než 100 stop. Těžba ropy z těchto nádrží představuje problémy především kvůli přítomnosti plynového uzávěru a vodonosné vrstvy, stejně jako umístění vrtů vzhledem ke kontaktům kapaliny. . Dynamika plynového uzávěru a vodonosné vrstvy ovlivňují produkci ropy a pečlivé umístění vrtu je nezbytné pro optimalizaci obnovy a minimalizaci vlivu těchto faktorů. Tento projekt si klade za cíl předpovědět produkční výkonnost horizontálního vrtu v tenkém ropném ráfku pomocí simulátoru Eclipse. K dosažení tohoto cíle byl vytvořen model tenkého olejového ráfku pomocí simulačního softwaru ECLIPSE. Bylo simulováno a analyzováno několik scénářů zahrnujících různé injekční tekutiny, délku horizontálního vrtu, typy vrtů a strategie umístění vrtu. Tyto scénáře byly porovnány se základním případem, aby se vyhodnotila kumulativní produkce ropy, vody a plynu. Zjištění odhalují, že prodloužení délky horizontálního vrtu z 1800 stop na 2700 stop zvyšuje produkci ropy o 17,5 % (z 2745440.5 na 3225610.8 stb). Vstřikování vody horizontálními vrty vykazuje nejvyšší produkci ropy (2786540.8 stb) ve srovnání s vertikálními vrty. Vstřikování plynu dvěma vertikálními vrty však přináší dalších 20 % produkce ropy. Simulační studie navíc ukazuje, že nejúčinnější umístění vrtu nastává v hloubce 36 stop pod kontaktem plyn-olej (GOC) a 26 stop nad kontaktem voda-olej (WOC), což vede k maximální produkci ropy 2920763.5 stb. ve srovnání s jinými scénáři.
Anotace v angličtině
Thin oil rim reservoirs typically refer to reservoirs with a pay thickness of less than 100 ft. Extracting oil from these reservoirs presents challenges primarily due to the presence of a gas cap and aquifer, as well as the positioning of wells in relation to the fluid contacts. The gas cap and aquifer dynamics affect oil production, and careful well placement is essential to optimize recovery and minimize the influence of these factors. This project aims to predict the production performance of a horizontal well in a thin oil rim reservoir using Eclipse simulator. To achieve this objective, a thin oil rim model was created using the ECLIPSE simulation software. Multiple scenarios involving various injection fluids, length of horizontal well, types of wells, and well placement strategies were simulated and analyzed. These scenarios were compared against a base case to evaluate the cumulative production of oil, water, and gas. The findings reveal that extending the length of the horizontal well from 1800 ft to 2700 ft enhances oil production by 17.5% (from 2,745,440.5 to 3,225,610.8 stb). Water injection through horizontal wells exhibits the highest oil production (2,786,540.8 stb) compared to vertical wells. However, gas injection through two vertical wells yields an additional 20% of oil production. Moreover, the simulation study indicates that the most effective well placement occurs at a depth of 36 ft below the gas-oil contact (GOC) and 26 ft above the water-oil contact (WOC), resulting in a maximum oil production of 2,920,763.5 stb compared to other scenarios.
Klíčová slova
Klíčová slova: Okrajový zásobník ropy, horizontální vrt, vstřikování vody a plynu, umístění vrtu
Klíčová slova v angličtině
Keywords: Oil rim reservoir, horizontal well, Water and gas injection, well placement
Zásady pro vypracování
P r i n c i p l e s f o r t h e s i s e l a b o r a t i o n:
Oil rim reservoirs that are characterized by a thin layer of oil, usually with water beneath and gas above, have a thickness ranging from less than 30 to 90 feet, and may take on the shape of a pancake or rim. Because of their limited thickness, the hydrocarbon column in these reservoirs tends to be located mainly in the capillary transition zone, regardless of the rock type and properties. These reservoirs present a challenge for oil production, as the small length of reservoir contact in the oil column when a vertical well is drilled through the reservoir, together with a large pressure drop associated with flow into the well, makes vertical wells highly prone to coning, resulting in low productivity. Even when a thin oil reservoir is bounded by impenetrable rock, vertical wells can still have low productivity. However, horizontal wells can greatly increase the contact area with the reservoir and improve productivity up to five times that of vertical wells.
Developing and producing from such reservoirs presents technical and commercial challenges, including water/gas coning and breakthrough, complicated production and drive mechanisms, and low recovery factors. Additionally, business concerns and commercial arrangements need to be taken into account to make such projects economically viable. Therefore, a reliable understanding of the volumetric assessment, saturation distribution, flow dynamics from the capillary transition zone, and mobile oil distribution is crucial for the success of oil rim developments. This can be achieved through advanced well completion design, proactive reservoir management, and appropriate depletion strategies.
Thesis should contain following chapters /not binding/:
1. Introduction 1.2. Problem statment 1.3. Aim of project 2. Literature review
2.1. Oil rim reservoir
2.2. Method of drilling in oil rim
2.3. Challenges of production from thin oil rim
2.4. Production strategies in oil rim
2.5. Water and Gas coning
2.6. Horizontal Well
3. Methodology
3.1. Model Discription
3.2. Base case model
3.3. Simulation case studies
4. Results and Discussion
5. Conclusion
6. References
Zásady pro vypracování
P r i n c i p l e s f o r t h e s i s e l a b o r a t i o n:
Oil rim reservoirs that are characterized by a thin layer of oil, usually with water beneath and gas above, have a thickness ranging from less than 30 to 90 feet, and may take on the shape of a pancake or rim. Because of their limited thickness, the hydrocarbon column in these reservoirs tends to be located mainly in the capillary transition zone, regardless of the rock type and properties. These reservoirs present a challenge for oil production, as the small length of reservoir contact in the oil column when a vertical well is drilled through the reservoir, together with a large pressure drop associated with flow into the well, makes vertical wells highly prone to coning, resulting in low productivity. Even when a thin oil reservoir is bounded by impenetrable rock, vertical wells can still have low productivity. However, horizontal wells can greatly increase the contact area with the reservoir and improve productivity up to five times that of vertical wells.
Developing and producing from such reservoirs presents technical and commercial challenges, including water/gas coning and breakthrough, complicated production and drive mechanisms, and low recovery factors. Additionally, business concerns and commercial arrangements need to be taken into account to make such projects economically viable. Therefore, a reliable understanding of the volumetric assessment, saturation distribution, flow dynamics from the capillary transition zone, and mobile oil distribution is crucial for the success of oil rim developments. This can be achieved through advanced well completion design, proactive reservoir management, and appropriate depletion strategies.
Thesis should contain following chapters /not binding/:
1. Introduction 1.2. Problem statment 1.3. Aim of project 2. Literature review
2.1. Oil rim reservoir
2.2. Method of drilling in oil rim
2.3. Challenges of production from thin oil rim
2.4. Production strategies in oil rim
2.5. Water and Gas coning
2.6. Horizontal Well
3. Methodology
3.1. Model Discription
3.2. Base case model
3.3. Simulation case studies
4. Results and Discussion
5. Conclusion
6. References
Seznam doporučené literatury
Formal issues in accordance with the Dean's Directive A-14/5/SD of June 18, 2014 which regulates certain issues of the Study and Examination Code of UP, as amended by 1.9.2017 (A-17/4-SD).
Graphics: maps, figures, tables, etc. according to the supervisor's recommendation
Page range: 35 to 55 pages
Recommended sources:
Balogun O, Adepoju Y, Ogbuli A, Chukwunweike A (2015) Hydrocarbon resource development decision for gas reservoir with 10ft oil rim: Niger Delta case study. SPE paper 178382 presented at SPE Nigeria annual international conference and exhibition, Lagos, 4–6 Aug
Dilib FA, Jackson MD, Zadeh AM, Aasheim R, Arland K, Gyllensten AJ, Erlandsen SM (2015) Closed-loop feedback control in intelligent wells: application to a heterogeneous, thin oil-rim reservoir in the North Sea. SPE Res Eval Eng 18(1):69–83
Elharith M, Huey HY, Tewari RD, Claire L, Fawzi NSM, SchulzeRiegert R (2019) Integrated modelling of a complex oil rim development scenario under subsurface uncertainty. J Pet Explor Prod Technol 9(4):2417–2428
Fan Z, Cheng L, Song H, Wu X, Zhang A (2015) Fluid interface moving for the concurrent production of gas cap and oil ring of gas cap reservoirs. Pet Explor Dev 42(5):683–690
John IJ, Matemilola S, Lawal K (2019) Simple guidelines for screening development options for oil-rim reservoirs. SPE paper 198718 presented at SPE Nigeria annual international conference and exhibition, Lagos, 5–7 Aug
Jaoua M, Rafee M (2019) Optimization of oil production in an oil rim reservoir using numerical simulation with focus on IOR/ EOR application. SPE paper 196709 presented at SPE reservoir characterization and simulation conference and exhibition, Abu Dhabi, 17–19 Sept
Lawal KA, Wells IA, Adenuga AO (2010) Preliminary assessment of oil-rim reservoirs: a review of current practices and formulation of new concepts. SPE paper 136955 presented at SPE Nigeria annual international conference and exhibition, Calabar, 31 Jul.–7 Aug
Obidike P, Onyekonwu M, Ubani CE (2019a)"Exploitation of thin oil rim with large gas cap, a critical review. SPE paper 198724 presented at SPE Nigeria annual international conference and exhibition, Lagos, 5–7 Aug
Seznam doporučené literatury
Formal issues in accordance with the Dean's Directive A-14/5/SD of June 18, 2014 which regulates certain issues of the Study and Examination Code of UP, as amended by 1.9.2017 (A-17/4-SD).
Graphics: maps, figures, tables, etc. according to the supervisor's recommendation
Page range: 35 to 55 pages
Recommended sources:
Balogun O, Adepoju Y, Ogbuli A, Chukwunweike A (2015) Hydrocarbon resource development decision for gas reservoir with 10ft oil rim: Niger Delta case study. SPE paper 178382 presented at SPE Nigeria annual international conference and exhibition, Lagos, 4–6 Aug
Dilib FA, Jackson MD, Zadeh AM, Aasheim R, Arland K, Gyllensten AJ, Erlandsen SM (2015) Closed-loop feedback control in intelligent wells: application to a heterogeneous, thin oil-rim reservoir in the North Sea. SPE Res Eval Eng 18(1):69–83
Elharith M, Huey HY, Tewari RD, Claire L, Fawzi NSM, SchulzeRiegert R (2019) Integrated modelling of a complex oil rim development scenario under subsurface uncertainty. J Pet Explor Prod Technol 9(4):2417–2428
Fan Z, Cheng L, Song H, Wu X, Zhang A (2015) Fluid interface moving for the concurrent production of gas cap and oil ring of gas cap reservoirs. Pet Explor Dev 42(5):683–690
John IJ, Matemilola S, Lawal K (2019) Simple guidelines for screening development options for oil-rim reservoirs. SPE paper 198718 presented at SPE Nigeria annual international conference and exhibition, Lagos, 5–7 Aug
Jaoua M, Rafee M (2019) Optimization of oil production in an oil rim reservoir using numerical simulation with focus on IOR/ EOR application. SPE paper 196709 presented at SPE reservoir characterization and simulation conference and exhibition, Abu Dhabi, 17–19 Sept
Lawal KA, Wells IA, Adenuga AO (2010) Preliminary assessment of oil-rim reservoirs: a review of current practices and formulation of new concepts. SPE paper 136955 presented at SPE Nigeria annual international conference and exhibition, Calabar, 31 Jul.–7 Aug
Obidike P, Onyekonwu M, Ubani CE (2019a)"Exploitation of thin oil rim with large gas cap, a critical review. SPE paper 198724 presented at SPE Nigeria annual international conference and exhibition, Lagos, 5–7 Aug
Přílohy volně vložené
Yes
Přílohy vázané v práci
ilustrace, grafy, schémata, tabulky
Převzato z knihovny
Ne
Plný text práce
Přílohy
Posudek(y) oponenta
Hodnocení vedoucího
Záznam průběhu obhajoby
Production prediction of horizotal well from a thin oil rim using Eclipse simulator prezentation
The student presented his bachelor's thesis in a MS PowerPoint presentation.
The reviews of both supervisor (Dr. J. Ali) and reviewer (D. Šimíček, Ph.D.) were handled by their authors. The supervisor suggested a grade C. The reviewer pointed out some mistakes and also suggested grade C.
In the discussion of the committee members, Dr. J. Ali asked about influence of capillary pressure
on the models, D. Šimíček Ph.D.: requested explanation of some used abbreviations, and explanation of water production changes during the time, do. J. Jirásek pointe dout typos in the presentation,
Dr. P. Spirov asked about the residual oil saturation, and finally prof. Šráček inquired what boundary conditions were used for the modeling. Student answered sufficiently only part of the above-mentioned questions.
In the public discussion, no question arose.
The committee agreed on an overall evaluation – grade C.