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Abstract In static and dynamic reservoir modeling, results have shown that the quality and accuracy of the models are dependent on the quality of rock and fluid property inputs e.g. facies, porosity, hydrocarbon saturation, permeability, net sand etc. used in creating the models. Electrofacies (facies defined using electric well logs) are a key property, since most other properties demonstrate some trend with facies. The typical workflow in modeling electrofacies uses well logs and some type of supervised or hierarchical (unsupervised) technique to cluster/ index the data into a number of groups (electrofacies). The input well logs however tend to ‘correlate’ or ‘anti-correlate’ (sometimes very strongly) and do not truly form a set of ‘independent’ variables that ‘sense’ different attributes of the facies. This paper presents a statistical technique for identifying and assigning electrofacies using a multivariate analysis technique (Principal Component Analysis (PCA)) to create ‘eigen-variables’ from well logs. These eigen-variables contain all the original information in the well-logs and, in contrast to the well logs, are unique and ‘linearly independent’; therefore resulting in log signatures that are much better used in predicting electrofacies. We have used this technique to model electrofacies in the Bonga Deepwater field, and the results presented in this paper show a very robust facies network (based on ‘Indexation Phase’ Self-Organizing Maps - SOM) with a higher predictive accuracy than achieved using the well logs directly.
- Africa > Nigeria (0.29)
- North America > United States (0.28)
Optimization of Strategies for Natural Gas Utilization: Niger Delta Case Study
Ogbe, Emmanuel (African University of Science &Technology, Abuja, Nigeria) | Ogbe, David O. (African University of Science &Technology, Abuja, Nigeria) | Iledare, Omowumi (African University of Science &Technology, Abuja, Nigeria)
Abstract Nigeria is endowed with huge proven gas reserves estimated to be 184 trillion cubic feet (Tcf). It ranks as the seventh holder of natural gas reserves in the world, and the largest in Africa. Nigeria also flares more natural gas than any other country; it accounts for 12.5% of the world's annual gas flared equivalent to $2.0 billion of annual revenue wasted. There is crucial need, therefore, to reduce gas flaring and its environmental impacts, and to derive maximum economic benefits from gas production. The purpose of this paper is to identify options for natural gas utilization and to develop a model for optimizing the natural gas utilization strategies using the Niger Delta as a case study. A Linear Programming model is proposed consisting of an objective function that is based on maximizing profit derived from the various utilization projects in the Niger Delta subject to several constraints. The optimal utilization/decision is determined from the solution of the optimization model. Results obtained indicate that the optimal utilization for maximum profit include both current and planned projects such as the Liquefied Natural gas project at Bonny, supply of gas for domestic use and power generation, transport to West African countries, transport of natural gas to Algeria through the TransSaharan Gas Pipeline (TSGP), and sales of EOR products to market. Upcoming project such as the Olokola LNG was only profitable as the gas price increases. Sensitivity analysis is carried out to evaluate impact of changes in the input parameters on the objective function. Paper also discusses the impact of gas pricing on the implementation of the Nigerian gas master plan (NGMP). The model can be used to select which set of projects would provide maximum profits (net income) from several competing natural gas projects.
- Africa > Niger (1.00)
- Africa > Nigeria > Niger Delta (0.92)
- Energy > Oil & Gas > Upstream (1.00)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (0.46)
- Government > Regional Government > North America Government > United States Government (0.30)
- South America > Atlantic Basin (0.99)
- North America > Atlantic Basin (0.99)
- Europe > Atlantic Basin (0.99)
- (4 more...)
- Management (1.00)
- Facilities Design, Construction and Operation > Natural Gas Conversion and Storage > Liquified natural gas (LNG) (1.00)
- Facilities Design, Construction and Operation > Natural Gas Conversion and Storage > Compressed natural gas (CNG) (1.00)
- Data Science & Engineering Analytics > Information Management and Systems (1.00)
Abstract The XON field is one of the five fields in the Gbaran-Ubie node to supply gas to Nigeria Liquified Natural Gas and is a field case history to illustrate the techniques and benefits of field development optimization right from initial field optimization to well delivery. The XON AB4000X reservoir is one of the largest Non Associated Gas reservoir in SPDC and is expected to provide more than half the gas required for Gbaran Central Processing Facility capacity of 1Bscf. Gas reserves from the 2003 Field review went down from 1.6 Tcf to 1.25 Tcf post the drilling of XON 7 and forecast based on new volumes indicate that the planned total reservoir offtake of 500 MMScf/d (100 MMScf/d per 5 gas producer planned for the reservoir) will only be sustained for 3 years instead of 5+ years. Following this, it became necessary to accurately estimate the Gas Initially In Place(GIIP), Ultimate Recovery (UR) and also provide an optimum development plan for this reservoir based on the new available data. An optimisation optimization team was put in place to build new static and dynamic models based on new available data to be used for: Accurately estimate in place volumes and UR Optimise expected reserves the Reservoir Development Plan Support drilling campaign The optimization optimization results have led to increase in expectation GIIP to 2.03 Tcf, represent a 22% increase over the 2003 Field Review and a 63% over the 2005 estimate. The CIIP increased to 106.0 MMstb, representing a 23% over the 2003 FR estimate. Total gas recovery has also increase to 1.26 Tcf which is about 20% from 2003 Field Review (FR). Production rates increased from 100 to 150 MMScf and compression scope of about 500 Bscf to further add value to the filed development. Most of the wells were delivered as top quartile wells due to collaboration between the asset, project and well engineering teams.
Maximising Natural Gas Reserves and Profitability Through Best Practice Studies Methodologies: A case Example by SPDC Gas Cluster team
Udofia, Abasiubong (Shell Petroleum Dev. Co. Nigeria ) | Meijssen, Thomas (Shell Petroleum Dev. Co. Nigeria) | Ebong, Ufot (Shell Petroleum Dev. Co. Nigeria) | Foley, Mary (Shell Petroleum Dev. Co. Nigeria) | Sturman, Liz (Shell Petroleum Dev. Co. Nigeria)
Abstract Natural gas is becoming an increasingly important source of the world'senergy, with the growth in demand for it as a fuel being encouraged by globalconcern for the environment, gas lower price and relative abundant to otherenergy sources. This hyper growth in demand comes with its attendantchallenges. In Nigeria, the Liquefied Natural Gas (NLNG) plant in Bonny isundergoing rapid expansion to meet this growth in demand. For Shell PetroleumDevelopment Company Nigeria (SPDC), the challenge to prove up reserves to meetup with the attendant demand, through subsurface developmental studies is onethat is handle through the integration of innovative techniques andprocesses for integrated field studies. Nodal (cluster) development approach, Opportunity Realisation (ORP) and Hydrocarbon Development Planning (HDP)Processes, 3D-all- the -way (3DATW) modelling process and the application ofreservoir simulators interface with a surface facility network using theHydrocarbon Field Planning Tool (HFPT), are proven innovations. This paper highlights how these innovative integration and rigorousuncertainty management techniques have been used to prove up reserves andproduced robust development plans for the several Nodal gasdevelopment projects in SPDC, Nigeria, and poised to meet the NigerianLiquefied Natural Gas (NLNG) production trains 1–6 (T1–6) gas supplycontractual obligations. Introduction Natural gas is the fastest growing energy source worldwide (Ref. 1), and itwill continue to grow rapidly for several years. The growth in demand fornatural gas as a fuel has been encouraged by several factors. Primarily andmore crucial is the environmental concerns which has push the emergence ofnatural gas as the fuel of choice much faster than earlier envisioned. Secondlynatural gas, including unconventional gas, is available in abundant quantitiesin many parts of the world and thirdly the lower price of gas relative to otherfuels. This rapid growth in demand, coupled with the fact that the gas industryis highly influenced by political event, economic factors and its relationshipwith the oil industry, comes with its attendant challenges. The Nigeria LNG gas plant at Bonny is undergoing a period of rapid expansionwhere the SPDC share of gas supply is contracted to rise from 975 MMscf/d(T1–3) to 1589 MMscf/d (T1–5) by end 2005. With the final investment decisiontaken on the T6, SPDC's total contractual DCQ demand has risen to almost2Bscf/d. In order to meet this demand the SPDC management, at a high level SPDCDevelopment Strategy meet, set up an integrated subsurface development team andentrusted the team with the task of proving up gas reserves through integratedoil and gas development studies.
- Africa > Nigeria (1.00)
- North America > United States > Texas (0.47)