?1 Penroc Oil Corp., based in Hobbs, N.M., completed a Wolfcamp producer in Lea County’s San Simon Field, about 10 miles west of Eunice, N.M. The #2 State GC, Section 7-22s-35e, was tested pumping 138 bbl. of 43-degree crude, 146,000 cu. ft. of gas, and 21 bbl. of water per day through acid- and fracture-stimulated perforations at 11,243-11,304 ft. and 11,352-11,470 ft. Samson Oil & Gas Ltd., based in Perth, Australia, owns a 37% working interest. In May, Samson acquired the 320-acre half-section immediately west of the Penroc wells.

2 EOG Resources Inc. reported production averaging 2.85 million cu. ft. of gas and 6 bbl. of condensate per day in March at a Hugoton Embayment development test. The #1-1 Savage Heirs is located 3 miles northwest of Hugoton, Kan., in Section 1-33s-38w of west-central Stevens County. The EOG Resources well went on-line in February 2008 and produced 49.4 million cu. ft. of gas and 197 bbl. of condensate from an undisclosed Morrow zone above 6,600 ft. EOG Resources is based in Houston.

3 Downing-Nelson Oil Co. Inc., with headquarters in Hays, Kan., has completed an exploratory test on the Central Kansas Uplift about 3.5 miles southwest of Ellis, Kan. The eastern Trego County venture, #1-23 Marvin Reidel, Section 23-13s-21w, tested through perforations in the Arbuckle pumping oil at a natural rate of 65 bbl. per day.

4 Nineteen miles southeast of Canadian, Texas, Tulsa-based?Laredo Petroleum Inc. completed a new producer in its recently designated Begert “10” Field in the western Anadarko Basin.?The #1 Begert Trust 5, Section 5, Block 41, H&TC Survey, A-160, was drilled and completed in Granite Wash flowing 1.66 million cu. ft. of gas with 47 bbl. of 63-gravity condensate and 142 bbl. of water daily after fracture stimulation and perforation. With shut-in tubing pressure of 2,214 psi and flowing tubing pressure of 1,438 psi on an 18/64-in. choke, absolute open-flow was calculated at 3.49 million cu. ft. of gas daily.?The southeastern Hemphill County (RRC Dist. 10) prospect is an east offset to a dual Des Moines/Atoka producer completed by Laredo in May at its #1 Begert Trust 6 in Section 6, Block 41, H&TC Survey, A-1310. Laredo has a very active program in Hemphill County that dates to late 2007 and now includes at least 14 producers, with no dry holes.

5 Houston-based Apache Corp. finaled two development wells in the Anadarko Basin’s Harper County, Okla. The #6-16 State AA, Section 16-27n-25w, flowed 1.43 million cu. ft. of gas and 13 bbl. of water daily during initial tests of six intervals of Chester lime between 6,610 and 6,719 ft. Flowing tubing pressure was 118 psi on a 40/64-in. choke. The #7-16 State AA, in Section 16-27n-25w, was drilled to 6,956 ft., perforated in Cherokee at between 6,318-88 ft. and fractured in two stages. It pumped 42-gravity oil at an initial rate of 268 bbl. per day, with 162,000 cu. ft. of gas and 60 bbl. of water daily.

6 IHS Inc. reports that Denver-based St. Mary Land & Exploration Co. flowed 3.9 million cu. ft. of gas, 220 bbl. of condensate and 180 bbl. of water per day at an Anadarko Basin horizontal test completed five miles west of Bessie, Okla. The #4-26 Simpson, Section 26-11n-18w, was tested on a 30/64-in. choke producing from the Des Moines Granite Wash following fracture-stimulation in three stages. Flowing tubing pressure was gauged at 690 psi.

7 Tulsa-based Samson Resources Co. reported a preliminary flow rate of 2.49 million cu. ft. of gas, 55 bbl. of condensate and two bbl. of water per day at an Anadarko Basin development test drilled three miles southeast of Thomas, Okla.?The #1-8 Robinson, Section 8-14n-14w, northeastern Custer County, was tested on a 13/64-in. choke producing from the Red Fork at 10,748-10,824 ft. Shut-in and flowing tubing pressures were 1,843 psi and 1,701 psi. Drilled to 11,020 ft., #1-8 Robinson is offset to the southeast and southwest by abandoned Red Fork producers in Thomas South Field.

8 Chesapeake Operating Inc. completed a multi-zone Pennsylvanian producer in the western Arkoma Basin 7.5 miles southeast of Wardville, Okla. Located in Atoka County, #5-9 Jenkins, Section 9-1n-13e, tested on a 48/64-in. choke flowing gas at a commingled rate of 4.46 million cu. ft. per day, with 26 bbl. of water. Shut-in tubing pressure was 2,200 psi, with flowing tubing pressure of 860 psi. The 11,900-ft. Wesley West Field well was perforated and fractured in several Pennsylvanian formations between overthrusted Spiro at 8,847-61 ft. to Wapanucka at 11,700-11,705 ft. Chesapeake is based in Oklahoma City.

9 BP America Production Co.’s #19 Bell Heirs horizontal development well recorded an initial flow rate of 11.2 million cu. ft. of gas per day, with no water, in Red Oak-Norris Field about five miles east-northeast of Red Oak, Okla. Located in Section 21-6n-22e, northeastern Latimer County, the well was fractured-stimulated and tested on an unreported choke size. Respective shut-in and flowing tubing pressures were 2,222 psi and 1,591 psi.

10 IHS Inc. reports that Unit Petroleum Co. completed a Panola Field development test about two miles northeast of Wilburton in southeastern Oklahoma. Producing from two Lower Atoka zones, #9 Lively, Section 6-5n-20e, Latimer County, initially tested flowing 3.44 million cu. ft. of gas with 50 bbl. of water daily through perforations at 11,710-11,828 ft. Shut-in and flowing tubing pressures were 3,050 psi and 550 psi, respectively. Both zones were fracture-stimulated and tested on 32/64-in. chokes. Unit, based in Tulsa, has drilled nine Atoka wells in Panola since 2003 that have combined to produce 61 billion cu. ft. of gas.

11 Three Arkoma Basin producers in a horizontal Woodford pilot project were completed by PetroQuest Energy LLC of Lafayette, La.?The initial well, about four miles north of McAlester, Okla., #1-6H Kent, Section 6-6n-15e, Pittsburg County, flowed 1.48 million cu. ft. of gas and 759 bbl. of water per day on a open choke with 140-psi flowing tubing pressure. Subsequent tests were drilled with parallel north horizontal legs. The #1-31H Cantrell, Section 6-6n-15e, flowed 4.35 million cu. ft. of gas with 1,779 bbl. of water daily following fracture-stimulation. To the west, #2-31H Redbird, Section 6-6n-15e, was drilled with a north lateral and flowed 5.56 million cu. ft. of gas and 1,464 bbl. of water per day. The #1-31H Redbird flowed at an initial rate of 4.9 million cu. ft. of gas and 1,447 bbl. of water daily.

12 Hanna Oil & Gas Co., headquartered in Fort Smith, Ark., completed an Arkoma Basin discovery flowing 5.35 million cu. ft. of gas per day about three miles west of the town of Rock Island in southeastern Oklahoma. The #1-3 Carpenter, Section 3-8n-26e, was tested on a 48/64-in. choke producing from three fracture-stimulated zones in Morris. The 6,426-ft. wildcat logged the top of Morris at 3,632 ft. The northeastern Le Flore County discovery is about one mile west and north of Atoka producers on the western flank of Rock Island Field.

13 Fort Worth-based XTO Energy Inc. released preliminary results from the first horizontal Fayetteville shale discovery in Arkansas’ Independence County. The Arkoma Basin venture is about eight miles west of Pleasant Plains, Ark.?The #1-29H Grammer, in Section 29-11n-7w, flowed 782,000 cu. ft. of gas daily through perforations at an unreported depth. Initial shut-in pressure was 875 psi. The 5,735-ft. horizontal test has a true vertical depth of 3,900 ft. The company has a multi-well exploration program in the area and is seeking approval to drill a test about 4.5 miles to the northeast.?

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