Integrated reservoir modeling of two Urengoy gas fields
- Sofya Mustaeva (Novatek) | V. Vasilev (Novatek)
- Document ID
- Society of Petroleum Engineers
- SPE Russian Oil and Gas Exploration and Production Technical Conference and Exhibition, 16-18 October, Moscow, Russia
- Publication Date
- Document Type
- Conference Paper
- 2012. Society of Petroleum Engineers
- 3.3.6 Integrated Modeling, 4.3.1 Hydrates, 3 Production and Well Operations, 4.6 Natural Gas, 4.1.5 Processing Equipment, 5.1.5 Geologic Modeling, 5.7.2 Recovery Factors, 4.2 Pipelines, Flowlines and Risers, 5.5 Reservoir Simulation, 4.1.2 Separation and Treating, 2.4.3 Sand/Solids Control, 1.6 Drilling Operations
- 2 in the last 30 days
- 158 since 2007
- Show more detail
- View rights & permissions
|SPE Member Price:||USD 9.50|
|SPE Non-Member Price:||USD 28.00|
The paper presents the integrated reservoir simulation and optimization results of two onshore gas fields. The fields are tied to common separator node, and have the similar gas in place volumes and production potentials. The optimal production plan
for each field is the goal of the simultaneous development planning. Usually, separate field development plane does not consider surface facilities constraints, so overestimates the gas production amount and project lifetime. However, integrated "reservoir-well-pipeline" model allows to optimize the production system and reach the maximum gas production from each field. This paper presents the two gas field production optimization algorithm, also several development strategies with
common production facility constraints are discussed with results. The optimal two-field simultaneous development plan is calculated on integrated computer model taking into account production system constraints.
The two considered gas fields are located at Urengoy gas province in Russian Federation and are associated with Cenomanian deposits of the Upper Cretaceous period Pokurskaya suite. Gas sand has permeability about 1 Darcy, formation
gas is dry and contains more than 99 mol.% of methane. Gas formation is deposited at TVD about 1300 m, gross sand thickness is 20-30 m. GIIP density is 200-500 MMcm/km2, the net pay thickness varies in the range of 5-15 m. The formations
have extensive aquifer and the same gradient of hydrostatic pressure. The field's 1 and 2 initial gas reserves are 30 and 20 billion cubic meters of gas respectively.
One of the fields has been on production since 2009 by the 12 vertical wells with the existing network of gas pipelines processing. The second field is under investigation, 3D-seismic survey was made in 2010-2011. Also in 2011 successful
exploratory wells were drilled, now preparatory works for production drilling begun. Gas from the both fields gather at the single gas processing unit. The distance between field 1 and 2 is about 25 km, so the loss of pressure and temperature drop of
gas in transit will be quite large.
Thus, the fields have similar gas reserves, production potentials and single unit preparations. Traditional modeling of these fields separately and without regard to the collection system has several disadvantages: it does not take into account the
boundary conditions of the pipeline system and site preparation, interference in the network of wells and the technological limitations, the redistribution of flow in the network during development. Also, it becomes impossible to plan simultaneous
development in the future.
The integrated model of "reservoirs-wells-pipelines" allows correctly determine the flow rates of gas wells within the constraints of the surface infrastructure, to justify well operation modes. It becomes possible to plan the joint development of
several fields with a unified system of transportation. At the same time, optimization decreases the loss of reservoir energy, and increases gas production.
|File Size||288 KB||Number of Pages||5|