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• W2045304975 abstract "Members SPE-AIME Abstract This paper presents a case history of recent hydraulic fracturing treatments of the Morrow formation in southern Blaine and western Canadian counties of Oklahoma. Hydraulic stimulation has often been avoided in the past because of water-sensitive clays commonly found in the Morrow formation. However, recent field results by Sun show that the Morrow in this area can be successfully and profitably fractured. Included is a history of Morrow treatments in the area, a summarization of recent treatment techniques and their results. Also, an economic analysis of these results is included using two years of actual post-frac production history. Introduction The petroleum industry has spent a great deal of money on the development of the deep Morrow gas sands of western Oklahoma in recent years. In order to maximize the producing rates and ultimate recoveries of these wells, it is important to evaluate the feasibility of hydraulic stimulations. This study evaluated the Sun wells located in the southern one-half of Blaine County and the western one-third of Canadian County, as shown in Figure #1. The Morrow sand over much of this area has proven to be a prolific producer of natural gas. prolific producer of natural gas. Due to the high initial bottom-hole pressures, these wells are often good commercial producers without stimulation. Hence, to avoid the possibility of reservoir damage from swelling formation clays (Table 1), fracturing has generally been avoided. Due to this reluctance to treat and the low permeability typically found in the Morrow, many wells have been abandoned with relatively high bottom-hole pressures and significant reserves. Sun Gas has recently done considerable testing of the use of hydraulic fracturing in this area. The result has been multifold increases in deliverability with increased economically producible reserves. It is not the intent of this paper to explore the theory applicable to these treatments, but to present the results of actual field tests and economic evaluation of these results. HISTORY OF MORROW STIMULATIONS Three factors are significant for earlier treatments of the Morrow formation. The first is that only a small percentage of the wells were stimulated. (Figure 2). The second is that little or no proppant was used in these fracs. An average treatment might use 10,000 pounds compared to 30,000 to 75,000 pounds used in recent jobs. The third is that, with a few exceptions, the older wells treated were very poor wells prior to treatment. It was generally considered too risky to stimulate a well that was a commercial producer without stimulation. It is important to note that, despite these factors, the majority of the stimulations were successful. Research on Sun-operated wells in this area did not turn up a single instance where production was reduced as the result of a fracture treatment. Typically, the fracs prior to 1965 were gelled salt water fracs. These were fairly small in volume, averaging about 20,000 gallons compared to 40,000 to 60,000 gallons used in recent treatments. As mentioned previously, they normally contained 10,000 pounds of sand or sand and walnut hulls. Later, the trend was to use 20,000 to 40,000 gallons of gelled 3% HCl with similar sand concentrations. The treatments and results of Sun-operated wells are summarized in Table 2. TEST RESULTS To date, there have been seven tests with each well showing a significant improvement in deliverability as a result of fracturing. These tests, as is discussed in the case histories, range from new or recent completions to wells apparently near depletion. The average treatment paid out in 28 days. A summary of these tests is shown in Table 3. More specific data on three of the treatments are given below. P. 197" @default.
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• W2045304975 date "1983-02-27" @default.
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• W2045304975 title "A Case History-Fracturing the Morrow in Southern Blaine and Western Canadian Counties, Oklahoma" @default.
• W2045304975 doi "https://doi.org/10.2118/11567-ms" @default.
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