1 Oxy Resources California LLC, Tupman, Calif., completed its #1 Jackson et al. new-field discovery in San Joaquin County, Calif., for 1.2 million cu. ft. of gas a day from perforations between 6,384 ft. and 6,426 ft. in the Mokelumne/Mokelumne River zone. The company tested the 6,700-ft. well, drilled in Section 4-2n-5e, through a 9/64-in. choke with 2,395 psi of flowing tubing pressure. 2 Alpine Inc., Edmond, Okla., has spudded the #1-15 Sand Springs in Section 15-11n-54e in northwestern Nye County, Nev. The 5,000-ft. wildcat is off the eastern flank of Little Smoky Valley, about 23 miles west of Currant and 17 miles northwest of Trap Springs Field in Railroad Valley. Alpine has another wildcat staked some 12 miles to the west-southwest in Little Smoky Valley. According to IHS Energy, Alpine plans to drill the #1-35 Needle Springs-Federal well to 9,000 ft. in Section 35-11n-52e, also in Nye County. 3 Englewood, Colo.-based independent Gasco Energy Inc., working under the Pannonian Energy Inc. name, plans an 11,760-ft. wildcat on the southwestern flank of the Uinta Basin in Section 21-11s-15e in southeastern Duchesne County, Utah. The #31-21-11-15 Gate Canyon State is about 22 miles north-northeast of Sunnyside, Utah, in a nonproducing township about four miles north-northwest of Nine Mile Canyon Field. The discovery well in that field, drilled in 1962, tested 2.4 million cu. ft. of gas a day from Wasatch between 3,782 and 4,044 ft. and smaller amounts of gas from Mesaverde between 6,983 and 7,198 ft. An 11,102-ft. dry hole, the nearest drilling to a comparable depth, lies some eight miles northeast of the Pannonian site. 4 Continental Resources Inc., Enid, Okla., made a discovery at its #1-18 Evaline, flowing 82 bbl. of oil and 202 bbl. of water per day from Lodgepole. The well is on the Fort Peck Indian Reservation, in Section 18-30n-45e, Valley County, Mont. It produces from three Lodgepole intervals between 6,536 and 6,842 ft. The company has also staked the #1-7 Joseph, a 7,200-ft. Lodgepole test, a half-mile north-northeast of the discovery in Section 7 of the same township. There is no other Lodgepole production in this part of Montana, says IHS Energy. 5 Headington Oil LP, Dallas, tapped Bakken with a dual-lateral discovery in Section 18-24n-55e, Richland County, Mont., that tested 445 bbl. of oil per day. The #21X-18-WCA Foundation produced through two open-hole fractured zones. The well is on the western flank of the Williston Basin, about 22 miles east-northeast of Richey, Mont. The first lateral ran southeast to 14,650 ft. measured depth (9,952 ft. true vertical depth), while the second lateral traveled south-southwest to 13,960 ft. measured depth (9,934 ft. vertical depth). Last summer, Lyco Energy Corp. completed the single-lateral #8-04-H Snydley-Vaira 1.5 miles northeast of the discovery to extend Spring Lake South Field to the southwest. That firm has staked the #7-15H Snydley-Vaira as a southeast offset to the Headington discovery. 6 Tulsa-based Zinke & Trumbo Inc. plans an exploratory program to test the Madison formation from two to five miles southwest of Alexander, N.D. It has asked the North Dakota Industrial Commission for six 640-acre drilling units in all of sections 22 to 27 in 150n-102w in northwestern McKenzie County. No wells have been drilled in any of the sections. The parcel is nearly 3.5 miles west of Pronghorn Field, which has produced 581,000 bbl. of oil, 692.6 million cu. ft. of gas and 1.33 million bbl. of water, primarily from Madison, since 1981. That field produced from deeper Red River and Duperow before producing from Madison. 7 Anadarko E&P Co. LP, Houston, plans a four-well wildcat program in the Washakie Basin about 34 miles southwest of Wamsutter in Sweetwater County, Wyo. One well is the #14-1 Fort La Clede, in Section 14-17n-98w, about three miles northwest of the BP America Production Co. #29-2 NW Iron Pipe discovery that flowed 1.6 million cu. ft. of gas and 11 bbl. of condensate a day from Lewis. Seven miles southeast of the Fort LaClede well, in Section 9-16n-97w, Anadarko plans the #9-1 Manuel Gap to Almond at 14,250 ft. It's about two miles northeast of an Iron Pipe Field well. A third wildcat is the #31-1 Horseshoe Bend in Section 31-17n-95w, also targeting Almond at 13,250 ft. That well is nearly two miles northeast of a Mesaverde gas discovery that flowed 511,000 cu. ft. of gas and eight bbl. of water a day from Almond. The fourth wildcat is about 15 miles north of the Horseshoe Bend test. That well, the #17-1 Desert Flats, is in Section 17-19n-95w. It will look at Lewis and Almond to about 10,100 ft. It is near the Desert Flats Field discovery well, which was completed for 19 bbl. of oil, 327,000 cu. ft. of gas and six bbl. of water per day from a fractured Almond interval, says IHS Energy. 8 Casper-based independent True Oil Co. discovered 960,000 cu. ft. of gas, 10 bbl. of condensate and three bbl. of water a day from the Lewis formation between 11,150-60 ft. at its #33-6 Western-Federal. Flowing tubing pressure was 1,700 psi at the well, drilled in irregular Section 6-15n-94w in southeastern Sweetwater County, Wyo., about 25 miles south of Wamsutter. 9 Burlington Resources Inc., Houston, completed two new wells in its Madden Deep Field on the northern flank of the Wind River Basin in Fremont County, Wyo., for high production rates. On the eastern side of the field in Section 35-39n-90w, Burlington completed the Big Horn #8-35 at 24,966 ft. for an initial production rate of 45 million cu. ft. of gas a day. The well cost $34 million to drill. The second well is nine miles west in Section 34-39n-91w, where the Big Horn #7-34 tested 56 million cu. ft. from Madison formation perforations between 24,118 and 24,378 ft. in the 24,525-ft. well. These are the fifth and sixth wells in the giant sour-gas field, and Burlington is drilling ahead on the Big Horn #9-4 in Section 4-38n-90w to a projected depth of 24,500 ft., says The Rocky Mountain Oil Journal. The Big Horn #6-27 was the deepest well drilled in the Rockies: 24,855 ft. Information is tight, but Burlington apparently found the gas-water contact with this northern field well. 10 EOG Resources Inc., Houston, hit a 140-bbl.-per-day discovery with 318,000 cu. ft. of gas and 12 bbl. of water per day at its #3-1 Crotalus wildcat on the southwestern flank of the Powder River Basin. The Converse County, Wyo., well is in Section 1-38n-76w, about 30 miles north of Glenrock. The well produced from fractures in the second bench of First Frontier between 12,540-60 ft. through a 12/64-in. choke with 1,425 psi of casing pressure. 11 L.L. Tuck (Great Plains Resources Inc.), Littleton, Colo., received a permit for a 5,000-ft. test in Lantry Field, an isolated field some seven miles east of Dupree in southwestern Dewey County, S.D. The #11-29 Little Skunk is in Section 29-13n-22e, and is an offset to a 1971 well that showed an initial potential of 25 bbl. of oil and 650 bbl. of oil per day from Red River between 5,054-70 ft. 12 Denver independent Patina Oil & Gas Corp. has asked for permits for five Mesaverde coalbed-methane tests in Moffatt County, Colo., on the southern flank of the Sand Wash Basin some 20 miles west-northwest of Craig. The wells are in township 7n-94w and scheduled to depths between 3,360 and 4,000 ft. They are the #8-7 Levi in Section 8, the #9-5 McRaider in Section 9, the #5-15 McThunder in Section 5, the #4-13 McSocks in Section 4 and the #8-1 Lillie Pie, also in Section 8. Patina drilled four tests in the same area last summer. 13 V.F. Neuhaus Properties Inc., McAllen, Texas, has scheduled a wildcat about 22 miles southeast of Pagosa Springs in Archuleta County, Colo. The #26-1 Price-Federal, staked in Section 26-33s-2e, is on the northern end of the Brazos Uplift, according to IHS Energy. The company plans to drill the well to 2,000 ft. to Cretaceous Greenhorn lime and Dakota sand. The well is about a mile south-southwest of Price Gramps Field, now inactive. The field produced 6.8 million bbl. of oil and 21.1 bbl. of water during its life, primarily from Dakota shallower than 1,500 ft. 14 ConocoPhillips Alaska Inc. may have up to 10 satellite oil fields within 30 miles of its Alpine Field on the North Slope of Alaska. The company said it also might need a stand-alone processing unit in the National Petroleum Reserve-Alaska or at Kuukpik, northeast of the Colville River Unit, to handle planned gas production. That unit would only be necessary to process gas that would feed into a gas pipeline to the lower 48 states.

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