Saline Reservoir Storage in an Active Oil Field: Extracting Maximum Value From Existing Data for Initial Site Characterization; Southeast Regional Carbon Sequestration Partnership (SECARB) Phase III

2010 ◽  
Author(s):  
Robin L. Petrusak ◽  
Shawna Cyphers ◽  
Stephen Blair Bumgardner ◽  
Denise Hills ◽  
Jack Pashin ◽  
...  
Keyword(s):  
Carbon Sequestration ◽  
Site Characterization ◽  
Oil Field ◽  
Phase Iii ◽  
Reservoir Storage ◽  
Maximum Value ◽  
Existing Data ◽  
Saline Reservoir

scholarly journals Planning saline reservoir storage developments — The importance of getting started early

2011 ◽  
Vol 4 ◽  
pp. 4575-4582 ◽  
Author(s):  
Bill Senior ◽  
John Bradshaw ◽  
Ananth Chikkatur ◽  
Mervyn Wright
Keyword(s):  
Reservoir Storage ◽  
Saline Reservoir

Pre-site Characterization Risk Analysis for Commercial-Scale Carbon Sequestration

2014 ◽  
Vol 48 (7) ◽  
pp. 3908-3915 ◽  
Author(s):  
Zhenxue Dai ◽  
Philip H. Stauffer ◽  
J. William Carey ◽  
Richard S. Middleton ◽  
Zhiming Lu ◽  
...  
Keyword(s):  
Carbon Sequestration ◽  
Risk Analysis ◽  
Site Characterization ◽  
Commercial Scale

Near-Surface Monitoring of Large-Volume CO2 Injection at Cranfield: Early Field Test of SECARB Phase III

SPE Journal ◽  
2013 ◽  
Vol 18 (03) ◽  
pp. 486-494 ◽  
Author(s):  
Changbing Yang ◽  
Katherine Romanak ◽  
Susan Hovorka ◽  
Robert M. Holt ◽  
Jeff Lindner ◽  
...  
Keyword(s):  
Carbon Sequestration ◽  
Shallow Groundwater ◽  
Soil Gas ◽  
Phase Iii ◽  
Co2 Injection ◽  
Co2 Leakage ◽  
Gas Monitoring ◽  
Near Surface ◽  
Surface Monitoring ◽  
Gas Component

Summary An early field project of the Southeast Regional Carbon Sequestration Partnership (SECARB) was conducted in Cranfield oil field, western Mississippi. Carbon dioxide (CO2) was injected into coarse-grained fluvial deposits of the Cretaceous lower Tuscaloosa formation, forming a gentle anticline at depths of 3300 m. CO2 injection started in July 2008, increasing to 23 wells (as of May 2011), with total injection rates greater than 1 million tons/yr. Focused monitoring programs of the deep subsurface and near surface have been implemented in different study areas. Here we present results of the near-surface monitoring program over a 3-year period, including shallow groundwater monitoring and soil-gas monitoring. A general methodology of detecting CO2 leakage into shallow groundwater chemistry is proposed. A set of geochemical indicator parameters was identified on the basis of the characterization of groundwater geochemistry, and these were further tested and validated using numerical modeling approaches, laboratory experiments, and field experiments. For soil-gas monitoring, a site (P-site) containing a plugged and abandoned well, a nearby open pit, and an engineered pad (representing a typical industrial near-surface environment for soil-gas monitoring) was selected for detailed study. The site was heavily instrumented with various sensors for measuring soil-gas concentrations at different depths, soil-water content, matric potential, and weather information. Three monitoring technologies were assessed: soil CO2 concentration measurements, CO2 flux measurements on the land surface, and multiple soil-gas component measurements. Results indicate that soil-gas-component measurements provide reliable information for gas-leakage detection. Methodologies of near-surface monitoring developed in this study can be used to improve CO2-leakage monitoring at other CO2 sequestration projects. This early field project was funded by the US Department of Energy, National Energy Technology Laboratory, as part of the Regional Carbon Sequestration Partnerships (RCSP) program. SECARB is led by the Southern States Energy Board (SSEB).

scholarly journals Investigation of PH effect in a mixture of basalt and iron on co2 sequestration in synthetic brines

2019 ◽  
Vol 7 (2) ◽  
pp. 112
Author(s):  
Toluwaleke Ajayi
Keyword(s):  
Carbon Sequestration ◽  
Host Rock ◽  
Co2 Sequestration ◽  
Ph Effect ◽  
Oil Field ◽  
Carbonate Mineral ◽  
Buffer Solution ◽  
Ph Response ◽  
Long Term Storage ◽  
Subsequent Step

CO2 sequestration in deep saline aquifers is a critical component of long-term storage options. It is suggested that the precipitation of mineral carbonates is mostly dependent on brine pH and is favoured above a basic pH of 9.0. However, brine pH will drop to acidic values once CO2 is injected into the brine. Therefore, there is a need to raise brine pH and maintain it stable. Synthetic brines were used here instead of natural brines because of the difficulty in obtaining and storing natural brines. Therefore, experiments were conducted to prepare a series of synthetic brines and to compare their suitability to natural brines for carbon sequestration. A typical formation rock (basalt) and a buffer solution (0.3M Tris buffer solution) were selected to buffer brine pH. The results show that synthetic brines prepared can be used as analogues to natural brines for carbon sequestration studies in terms of chemical composition and pH response. This study investigates the effect of iron ( ) in the pH of six synthetic brines prepared as analogue to oil-field brine by conducting a pH stability studies for CO2-brine experiment and CO2-basalt-brine experiment. In a subsequent step, studies were conducted to correlate how brine samples respond in the presence of basalt and the buffer solution. X-Ray powder Diffraction (XRD) analyses were also carried out to characterise the mineralogy of the synthetic brines. The result of the XRD confirmed that calcite was the major component that was dominated in the -brine–experiment while slight occurrence of calcite, iron oxyhydroxides and dolomite precipitated in the -rock-brine experiment. It was observed that ferric iron  and its reaction with host rock (basalt) did not contribute to pH instability therefore making it suitable for precipitation of carbonate mineral while ferrous iron in the absence of host rock did not contribute to pH instability therefore making it also suitable for precipitation of carbonate mineral.   

THE TARBAT-IPUNDU OIL FIELD, A CASE STUDY IN IDENTIFYING BYPASSED OIL

1998 ◽  
Vol 38 (1) ◽  
pp. 36
Author(s):  
T.P. Lonergan ◽  
P.G. Ryles ◽  
S.T. McClure ◽  
D.W. McMillan
Keyword(s):  
Multidisciplinary Team ◽  
Development Program ◽  
Oil Field ◽  
Growth Potential ◽  
Total Production ◽  
Field Development ◽  
The North ◽  
Bypassed Oil ◽  
Existing Data ◽  
Eromanga Basin

Since 1995 the Tarbat-Ipundu Field has developed from a marginal 200 BOPD (31.8 kL/d) field with perceived limited growth potential to a developing resource with production up to 3,000 BOPD (476.9 kL/d). This increase was achieved through the efforts of a dedicated multidisciplinary team and an aggressive 'fit for purpose' drilling and evaluation program.The Tarbat-Ipundu Field is located in PL 52 of ATP 299P in southwestern Queensland, approximately 115 km to the northeast of the Jackson Oil Field. The field was discovered by Hartogen Energy Ltd in 1986 with the drilling of Ipundu 1 which came on-line at 100 BOPD (15.9 kL/d) from the Wyandra Sandstone and the Murta Member. The discovery well was followed by the drilling of Tarbat-1 in 1988 on a subculmination to the north. Tarbat-1 encountered oil in the Wyandra Sandstone but watered out after producing 17 KSTB (2,702 kL) of oil. During 1991 a further four wells were drilled in the Ipundu Field by the then operator, Ampolex Pty Ltd. Two of these wells were plugged and abandoned. In January 1994 the field was producing at 220 BOPD (34.9 kL/d) after a total production of 350 KSTB.The Santos Group acquired a majority interest and Operatorship of the Tarbat-Ipundu Field in 1994. An integrated geological and engineering evaluation of Tarbat-1, incorporating experience gained in other parts of the Eromanga Basin, indicated the potential for bypassed oil in the Hutton Sandstone. Similarly, additional potential was recognised in the Wyandra Sandstone and Murta Member in the Tarbat-Ipundu wells. To evaluate this potential Tarbat-2 was drilled in August 1995 at a location 315 m to the northwest of Tarbat-1. Drill stem tests in Tarbat-2 resulted in flows of 2,037 BOPD (323.8 kL/d) from a 26 m gross hydrocarbon column in the Hutton Sandstone and 770 BOPD (122.4 kL/d) from a 14 m gross hydrocarbon column in the Wyandra Sandstone.An aggressive appraisal and development program followed the drilling of Tarbat-2 which has resulted in the drilling of an additional 25 wells. Proved and Probable Oil in Place estimates have increased from 5.2 MMSTB (0.826 ML) in 1994 to 44.2 MMSTB (7.02 ML) in 1997. As at June 1997 the field produces oil from the WyandraSandstone, Murta Member and Hutton Sandstone of the Eromanga Basin. A combined oil offtake of up to 3,000 BOPD (476.9 kL/d) has been achieved from the field. Continued field development is planned for 1998.The successful 're-discovery' of the Tarbat-Ipundu Field illustrates the potential benefit of a systematic review and integration of all existing data via a multidisciplinary team. The increasing cost of new data acquisition makes it imperative that the existing data is thoroughly evaluated prior to the investment of further exploration capital. The Tarbat-Ipundu Field demonstrates the potential to add significant new reserves from focussed targeting and evaluation of potential bypassed hydrocarbon accumulations.

scholarly journals Application of Double-Difference Seismic Tomography to Carbon Sequestration Monitoring at the Aneth Oil Field, Utah

Minerals ◽  
2013 ◽  
Vol 3 (4) ◽  
pp. 352-366
Author(s):  
Brent Slaker ◽  
Erik Westman ◽  
Kray Luxbacher ◽  
Nino Ripepi
Keyword(s):  
Carbon Sequestration ◽  
Seismic Tomography ◽  
Oil Field ◽  
Double Difference
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