Technical Evaluation of Secondary Oil Recovery Methods, A Case Study on One of the Iranian HPHT Carbonate Reservoirs
- S. Sajjadian (National Iranian Oil Company (NIOC)) | V. Mahmoudian Ataabadi (National Iranian Oil Company (NIOC)) | M. Dalaei (National Iranian Oil Company (NIOC))
- Document ID
- Society of Petroleum Engineers
- Nigeria Annual International Conference and Exhibition, 6-8 August, Lagos, Nigeria
- Publication Date
- Document Type
- Conference Paper
- 2012. Society of Petroleum Engineers
- 4.1.2 Separation and Treating, 5.5.2 Construction of Static Models, 4.1.4 Gas Processing, 1.6.9 Coring, Fishing, 5.4.2 Gas Injection Methods, 5.1 Reservoir Characterisation, 7.2.2 Risk Management Systems, 6.1.5 Human Resources, Competence and Training, 1.8 Formation Damage, 5.2 Reservoir Fluid Dynamics, 5.2.2 Fluid Modeling, Equations of State, 4.3.3 Aspaltenes, 5.8.7 Carbonate Reservoir, 4.6 Natural Gas, 5.7.2 Recovery Factors, 5.6.4 Drillstem/Well Testing, 4.1.5 Processing Equipment, 6.5.2 Water use, produced water discharge and disposal, 5.1.5 Geologic Modeling, 4.5 Offshore Facilities and Subsea Systems, 5.2.1 Phase Behavior and PVT Measurements
- 0 in the last 30 days
- 335 since 2007
- Show more detail
- View rights & permissions
|SPE Member Price:||USD 8.50|
|SPE Non-Member Price:||USD 25.00|
The reservoir under study is a HPHT (high pressure-high temperature) reservoir with high amount of H2S and asphaltene. It has more than 1 billion of recoverable oil as static geological model estimated but the problem is the only drive mechanism is Solution gas drive and it has no active aquifer so although it had good flow potential but what if it drops lower than bubble point pressure? Dynamic model showed it was to deplete quickly. By using new reservoir management techniques and enhanced oil recovery in order to pressure maintenance one can recover a lot more oil.
The scope of this project was to evaluate in terms of impact of surface facilities, reserves and recovery factor of using gas injection and then different fluid composition for this field's gas injection
1. Water Injection
2. Rich gas corresponding to the associated separator gas to be re-injected to reservoir
3. Lean gas corresponding to the associated separator gas to be re-injected to reservoir after condensate removal
There are 40 wells in this fields and this was possible to change function of production well to injector if needed.
A team of Reservoir, Production, Process, Facility and Environmental engineers worked on the possibility of Secondary recovery by injection and its challenges.
Simulation models were run for different scenarios and realizations and the best composition of injection fluid was selected by considering reservoir rock and fluid data and different injecting fluid composition and different injection pressure.
After comprehensive study and technical evaluation it was found that. Miscible gas injection was the best scenario allowing 0.66 BSTB Recovery increase and 9 years longer plateau compared to Natural depletion.
Secondary recovery plays an important role in green fileds. The goal of this study is investigation of several secondary recovery strategies in order to optimize of a carbonate reservoir with short production history.
Oil reservoirs, following discovery, undergo production of oil by primary recovery. In primary recovery, the energy and pressures inherent in the reservoir are used to force the oil through the complex pore network toward the producing wells. The primary recovery mechanism can differ from one reservoir to another, depending on the type of reservoir and the properties of the rock and the hydrocarbons present. Following the primary stage, the reservoir energy is supplemented by the injection of water and/or gas in a "secondary recovery?? stage.
|File Size||242 KB||Number of Pages||7|