Layer | Fill | Outline |
---|
Map layers
Theme | Visible | Selectable | Appearance | Zoom Range (now: 0) |
---|
Fill | Stroke |
---|---|
Collaborating Authors
Results
Optimizing Oil Development of a Super K Compartmentalized Reservoir with Large Gas Cap and Bottom Water Aquifer Case Study
El Gazar, Ashraf (Abu Dhabi Company for Onshore Petroleum Operations Ltd.) | Bin Sumaidaa, Saleh A. (Abu Dhabi Company for Onshore Petroleum Operations Ltd.) | Alklih, Mohamad Yousef (Abu Dhabi Company for Onshore Petroleum Operations Ltd.) | Syofyan, Syofvas (Abu Dhabi Company for Onshore Petroleum Operations Ltd.) | Al Shabibi, Tariq Ali (Abu Dhabi Company for Onshore Petroleum Operations Ltd.)
Abstract This paper presents a case study of developing a significant volume of super K compartmentalized oil reservoir with a large gas cap and bottom water aquifer in Abu Dhabi-UAE. The reservoir is a low relief heterogeneous carbonate, located in a complex environment represented by natural and artificial islands in the surface, shallow and medium water marine areas with subsurface lateral, and vertical heterogeneities as well as variation in reservoir fluid properties. The static and dynamic data were utilized to construct representative geological and dynamic models for the reservoir. The field development objective focused on maximizing the oil production and achieving 70% RF while minimizing the gas cusping, water conning and early breakthrough via super K interval. Nine years production dynamic data were available from 6 oil producers in addition to well testing "14 wells", core "11 wells", MDT "17 wells" data during the appraisal phase. These data were used to quality control the initialization and history match phases. In preparation to the development options, the team included pressure support using water injection, lean gas injection, miscible gas injection, miscible WAG injection. The predicted reservoir performance of the super K oil reservoir indicated considerable gas production and high water production from the bottom water aquifer through super K interval in all the development options. It was a big challenge to reduce the amount of gas production, water production, and early breakthrough for all development options. A new development option was introduced to perform peripheral miscible Hydrocarbon WAG injection accompanied with optimization of the wells and completion intervals locations for producers and injectors, as wells as WAG cycle to minimize the gas production from the gas cap, water production from the aquifer, and early breakthrough. This resulted in significant enhancement to plateau length, sweep efficiency, and recovery factor. This paper provides the methodology followed to guide the development plan to fill in the uncertainty gap along with a detailed data acquisition and monitoring programs to better understand the reservoir behavior.
- Geology > Geological Subdiscipline > Economic Geology > Petroleum Geology (0.55)
- Geology > Rock Type > Sedimentary Rock > Carbonate Rock (0.49)
- Reservoir Description and Dynamics > Reservoir Characterization > Exploration, development, structural geology (1.00)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery > Waterflooding (1.00)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery > Miscible methods (1.00)
Field Development and Optimization Plan for Compartmentalized Oil Rim Reservoir
El Gazar, Ashraf Lotfy (Abu Dhabi Company for Onshore Petroleum Operations Ltd. (ADCO)) | Alklih, Mohamad Yousef (Abu Dhabi Company for Onshore Petroleum Operations Ltd. (ADCO)) | Sumaidaa, Saleh A. (Abu Dhabi Company for Onshore Petroleum Operations Ltd. (ADCO)) | Al Shabibi, Tariq Ali (Abu Dhabi Company for Onshore Petroleum Operations Ltd. (ADCO))
Abstract This work illustrates field development plan and optimization studies conducted on a Middle-Eastern carbonate reservoir. The field lies in an onshore area where increasing urbanization is complicating the field development with regard to safety, accessibility, and drilling sites. The reservoir exhibits relatively fair to poor reservoir characteristics and variable oil water contacts due to faulting, suggesting the presence of 5 different reservoir compartments. A total of 10 wells had penetrated the reservoir out of which 8 wells tested oil and suggested a huge initial gas cap while 2 others penetrated water leg. Six years of early production scheme (EPS, 4 producers, 1993 to 1998) data in addition to production testing, core (2 wells), MDT (3 wells), PVT (4 wells) data were gathered in order to identify the main uncertainties and test the feasibility of the full field development. EPS indicated production decline coupled with severe increase in GOR and water cut in some wells, after which the producing wells and facilities were P&A due to safety concerns and low productivity. A number of parameters were addressed and optimized during the full field development plan. These include formation evaluation and modeling parameters based on EPS findings, the limited available data, and pressure support mechanism. Several development scenarios were constructed, consisting of various combinations of horizontal producers and injectors and considering natural depletion, WI, GI, and WAG scenarios targeting the proven reserves. The dynamic modeling suggests that an ultimate recovery of 70% can be achieved by the different injection scenarios. However, considering the complexity of the surrounding environment and the size of the prize, it is recommended that the field development would be economically viable for a period of 10 years under natural depletion, provided the most effective development strategy in terms of number, location, orientation and horizontal reach is adopted.
- Africa (0.68)
- North America > United States (0.46)
- Asia > Middle East > UAE > Abu Dhabi Emirate > Abu Dhabi (0.15)
- Geology > Structural Geology > Fault (0.94)
- Geology > Rock Type (0.93)
- Geology > Geological Subdiscipline > Economic Geology > Petroleum Geology (0.64)
- Geophysics > Seismic Surveying (1.00)
- Geophysics > Borehole Geophysics (1.00)
- Europe > Norway > North Sea > Central North Sea > Central Graben > Block 2/8 > Valhall Field > Tor Formation (0.99)
- Europe > Norway > North Sea > Central North Sea > Central Graben > Block 2/8 > Valhall Field > Hod Formation (0.99)
- Europe > Norway > North Sea > Central North Sea > Central Graben > Block 2/11 > Valhall Field > Tor Formation (0.99)
- Europe > Norway > North Sea > Central North Sea > Central Graben > Block 2/11 > Valhall Field > Hod Formation (0.99)
Challenges and Lessons Learned from Developing a Thin Super K Complex Carbonate Oil Reservoir with Gas Cap and Active Water Drive - A Case Study from the Middle East
Alklih, Mohamad Yousef (Abu Dhabi Company for Onshore Oil Operations (ADCO)) | Bin Sumaidaa, Saleh A. (Abu Dhabi Company for Onshore Oil Operations (ADCO)) | El Gazar, Ashraf Lotfy (Abu Dhabi Company for Onshore Oil Operations (ADCO)) | Knytl, Jan (Abu Dhabi Company for Onshore Oil Operations (ADCO)) | Ali Khan, Muhammad Kamran (Abu Dhabi Company for Onshore Oil Operations (ADCO)) | Abu Baker, Aida Shafina (Abu Dhabi Company for Onshore Oil Operations (ADCO))
Abstract This paper presents a case study of developing a complex super k thin carbonate reservoir with a thin upper super permeable layer with a significant volume of oil, a gas cap and an active water drive in Abu Dhabi-UAE. The field lies in a coastal marine area covering mainland, natural and artificial islands as well as shallow and deep marine areas. The reservoir lies within a relatively low relief heterogeneous carbonate structural trap originally deposited within a complex depositional environment, characterized by lateral and vertical variations in reservoir rock and fluid properties. Six years of production dynamic data are available from oil producers in addition to well testing and MDT data. The production is constrained by the presence of a high permeable streak just below the dense carbonate top seal and bounded by gas cap above and water below. This streak dominates the drainage of reservoir in such a way that the majority of the wells completed suffer from early apparent gas cusping and increasing water production. The reservoir has been penetrated by vertical, deviated and horizontal wellbores. In relation to this, differences in production performance have been observed, specifically with respect to gas oil ratio and water cut. During the early development stage, three horizontal holes were drilled, however due to the difficulties of proper geo-steering of the horizontal hole placement within the thin oil column, two holes were placed in the gas cap and the third was placed in water. The main challenges of current and future development plans are the optimization of well design, placement and completion strategy to avoid the gas cap and transition zone. This paper discusses the lessons learned from the ongoing development of the mentioned reservoir and the way forward for the future development phases.
- Geology > Sedimentary Geology (1.00)
- Geology > Geological Subdiscipline > Economic Geology > Petroleum Geology (0.50)
- Geology > Rock Type > Sedimentary Rock > Carbonate Rock (0.49)
- Reservoir Description and Dynamics > Reservoir Characterization > Exploration, development, structural geology (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Drillstem/well testing (1.00)
- Management > Professionalism, Training, and Education > Communities of practice (1.00)
- Data Science & Engineering Analytics > Information Management and Systems > Knowledge management (1.00)