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An extensive reservoir management program in a hydrocarbon miscible flood has allowed the reservoir team to stay abreast of reservoir performance and to influence ultimate recovery of oil. A key component of this program, operated by Canadian Hunter Exploration Ltd. at the Brassey miscible flood in British Columbia, included the downhole manufacture of tritiated methane as part of an innovative tracer injection program. Other technical elements in the reservoir management program include frequent pressure surveys, volume monitoring, and compositional analysis. Teamwork between geologists, reservoir engineers, production/facilities engineers, and field operations staff was absolutely essential to the success of the program. Introduction The reservoir management program at Brassey has enabled the business unit reservoir team to evaluate performance and influence ultimate recovery of oil from the miscible flood. The program was implemented by field operator Canadian Hunter Exploration Ltd., with the assistance of its partner, BP Exploration Inc. and affiliate BP Research. The program included depletion design using full-field black oil and later compositional modelling; a regular, frequent data collection and monitoring program; and feedback of results to field operations staff and to the reservoir simulation team. Key objectives in managing the field arc to maintain pressure above the minimum miscibility pressure, and to balance flood fronts in each pattern to minimize breatkthrough gas production. Technical elements in the reservoir management program include an innovative tracer program which involved the first downhole manufacture of tritiated methane, frequent pressure surveys, voidage monitoring, and compositional analysis. The need for a tracer program was identified early in the design of the five-spot pattern gas miscible flood in order to determine the source of gas breakthrough. Tritiated methane (CH3T), krypton-95 (Kr-85), and sulphur hexafluoride (SF6) were selected as tracers of choice in the five-pattern flooded area. Other tracers considered were halocarbons Freon-11, Freon-12, Freon-13B1 and Freon-114. A potential problem with radiolytic decomposition of tritiated methane led to development of an on-site, downhole manufacturing method. Tracer results to date have made it possible to identify the origin of breakthrough gas at several producing locations. This gas breakthrough has been counteracted by making adjustments to offset well production rates and by injection reallocation. Tritium and krypton have been detected at several wells, verifying the efficacy of the injection scheme. Sulphur hexafluoride has not yet been detected. Using the results of the surveillance program, an effective history match is being constructed for a full-field compositional model, and the information gleaned from the tracer results in particular has added considerable confidence to the accuracy of the match. Reservoir Description The Brassey field, located in northeast British Columbia, Canada (Figure 1), produces oil from the Artex member of the Triassic Charlie Lake formation. The Artex lies at a depth of 10,000 feea, forming a stratigraphic trap with average net pay thickness of 10 feet, with porosities averaging 16 percent, water saturation of less than 2 percent and permeability of 152 md. The reservoir sand is interpreted to be an aeolian-deposited sand encased in an evaporitic platform sequence'. lateral sand pinchout forms an effective reservoir seal and renders the Brassey field a closed system. The sand is predominately quartz with minor amounts of chert, feldspar, sulfate and dolomite grains. P. 93^
An extensive reservoir management program in a hydrocarbon miscible flood has allowed the reservoir team to stay abreast of reservoir performance and to influence ultimate recovery of oil. A key component of this program, operated by Canadian Hunter Exploration Ltd. at the Brassey miscible flood in British Columbia, included the downhole manufacture of tritiated methane as part of an innovative tracer injection program. Other technical elements in the reservoir management program include frequent pressure surveys, volume monitoring, and compositional analysis. Teamwork between geologists, reservoir engineers, production/facilities engineers, and field operations staff was absolutely essential to the success of the program. Introduction The reservoir management program at Brassey has enabled the business unit reservoir team to evaluate performance and influence ultimate recovery of oil from the miscible flood. The program was implemented by field operator Canadian Hunter Exploration Ltd., with the assistance of its partner, BP Exploration Inc. and affiliate BP Research. The program included depletion design using full-field black oil and later compositional modelling; a regular, frequent data collection and monitoring program; and feedback of results to field operations staff and to the reservoir simulation team. Key objectives in managing the field arc to maintain pressure above the minimum miscibility pressure, and to balance flood fronts in each pattern to minimize breatkthrough gas production. Technical elements in the reservoir management program include an innovative tracer program which involved the first downhole manufacture of tritiated methane, frequent pressure surveys, voidage monitoring, and compositional analysis. The need for a tracer program was identified early in the design of the five-spot pattern gas miscible flood in order to determine the source of gas breakthrough. Tritiated methane (CH3T), krypton-95 (Kr-85), and sulphur hexafluoride (SF6) were selected as tracers of choice in the five-pattern flooded area. Other tracers considered were halocarbons Freon-11, Freon-12, Freon-13B1 and Freon-114. A potential problem with radiolytic decomposition of tritiated methane led to development of an on-site, downhole manufacturing method. Tracer results to date have made it possible to identify the origin of breakthrough gas at several producing locations. This gas breakthrough has been counteracted by making adjustments to offset well production rates and by injection reallocation. Tritium and krypton have been detected at several wells, verifying the efficacy of the injection scheme. Sulphur hexafluoride has not yet been detected. Using the results of the surveillance program, an effective history match is being constructed for a full-field compositional model, and the information gleaned from the tracer results in particular has added considerable confidence to the accuracy of the match. Reservoir Description The Brassey field, located in northeast British Columbia, Canada (Figure 1), produces oil from the Artex member of the Triassic Charlie Lake formation. The Artex lies at a depth of 10,000 feea, forming a stratigraphic trap with average net pay thickness of 10 feet, with porosities averaging 16 percent, water saturation of less than 2 percent and permeability of 152 md. The reservoir sand is interpreted to be an aeolian-deposited sand encased in an evaporitic platform sequence'. lateral sand pinchout forms an effective reservoir seal and renders the Brassey field a closed system. The sand is predominately quartz with minor amounts of chert, feldspar, sulfate and dolomite grains. P. 93^
SPE Members Abstract A compositional reservoir simulation evaluation' of the Brassey Artex B Pool, located in British Columbia, Canada, was undertaken to predict hydrocarbon recoveries under a variety of development schemes. The subject reservoir is a thin aeolian sand containing a volatile, highly undersaturated oil. A miscible flood was initiated in 1989 immediately following delineation drilling. The numerical model was constructed using the most up-to-date geological, geophysical, and petrophysical data. Surface facilities were incorporated into the model, through the use of individual well test separators for production tests performed prior to implementation of a miscible flood, and by a four-stage separator after implementation of the miscible flood. This model was then calibrated by history matching three years of volumetric and compositional data. Tracer survey results were also used in the model calibration phase. Reservoir fluid compositions were represented in the model with a nine pseudo-component Peng-Robinson equation of state. The equation of state was calibrated to laboratory constant composition expansion, differential liberation, swelling test, and slim tube data to provide representative PVT properties of the reservoir fluid and injected solvent. The history matched model was then used to forecast the production performance for a variety of production and injection schemes, including infill drilling and sensitivities to injected solvent composition. The reservoir fluid characterization phase of the study verified that the recovery process was one of first-contact miscibility at the 4000 psia operating pressure. Analysis of the pressure, saturation, and fluid composition distributions demonstrated that an effective first-contact miscible displacement was occurring in the reservoir. While the majority of the pool will be swept with the existing well configuration, two infill drilling locations have been identified. Phase behaviour analysis indicated that the current injection gas is richer than required to achieve first contact miscibility; therefore, liquids can be extracted and sold from the injection gas stream. History matching of the compositional model suggested an initial oil in place volume approximately one-third less than that derived from previous pseudo-miscible black oil studies. However, the initial analytical material balance estimates derived from production tests conducted prior to the miscible flood showed an oil in place volume midway between the two model estimates. This comparison highlighted the difficulties of characterizing the volumetric behaviour of near-critical fluids using either compositional or black oil techniques. Introduction The Brassey field, located in northeastern British Columbia, was discovered in 1979 with the drilling of the d-89-B/93-P-10 well (Figure 1). Test results showed the well to be in a limited reservoir, and no further drilling was done until 1987, when the d-71-C/93-P-10 well encountered the overpressed Artex member of the Triassic Charlie Lake formation. Delineation drilling followed over the ensuing two years, with seven oil-production wells and four gas-injection wells being drilled into the Artex B Pool, the largest of several Artex pools in the field and the subject of this paper. Due to the strongly oil-wet nature of the reservoir rock, concerns over water compatibility with the anhydrite present in the zone, and the very undersaturated oil, the decision was made to move directly to a miscible hydrocarbon gas injection development after delineation drilling. The final well configuration was five-spot injection pattern with wells on 320-acre spacing. P. 339^
Miscible flooding was invented many years ago, and in the 1950's it was viewed as one of the most promising techniques to use for improving oil recovery from a reservoir.1,2,3,4,5,6,7 Since that time many groups have researched what would be the most important parameters to optimize in the lab, have developed theoretical models to correlate these parameters, and then have implemented these "optimally designed" gas injection systems in the field. Amidst all the increase in technology and sophistication there is still ongoing debate as to whether one needs to achieve miscibility in order to optimize the recovery or whether a degree of immiscibility, characterized by the name "near miscible", is equally adequate for field implementation in enhanced oil recovery processes. This paper seeks to provide insight into these questions by reviewing some of the parameters which are at work in gas injection EOR as well as qualifying some of the techniques which can be used in designing gases for injection. Moreover, case histories are described herein where laboratory work was performed, phase behavior described, and then the gas injected into the reservoir. Results from the field are then shown and commentary included on the field performance.
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