1. Two commingled Hartford wells have been completed by Houston-based XTO Energy Inc. as part of Mansfield Field in Logan County, Ark. In Section 18-5n-29w, #4-18 Turner Unit tested at 1.97 million cu. ft. of gas per day through three fracture-treated intervals at 5,700-04 ft., 5,890-5,992 ft. and 6,476-6,628 ft. On a 24/64-in. choke, flowing and shut-in tubing pressures were gauged at 246 psi and 827 psi, respectively. Absolute open flow was calculated at 2.16 million cu. ft. per day. The new producer was vertically drilled to a total depth of 8,600 ft. Nearby, #1-18 Bobby Winters had an initial daily potential of 2.04 million cu. ft. of gas daily through three fracture-stimulated Hartford zones at 5,756-98 ft., 5,882-90 ft. and 6,182-6,426 ft. Respective flowing and shut-in tubing pressures were 250 psi and 675 psi on a 23/64-in. choke. Absolute open flow was calculated at more than 2.36 million cu. ft. per day.

2. Two horizontal wells in Beckville Field in Texas’ Panola and Rusk counties (RRC Dist. 6) were completed by Goodrich Petroleum Corp. of Houston. The #1H Billy Hay Harris flowed 12.2 million cu. ft. of gas per day. On a 24/64-in. choke, flowing tubing pressure was 6,000 psi. The 16,380-ft. well was completed with a 5,000-ft. lateral and 25 fracture stages. The surface location is in the Samuel Bowers Survey, A-101. A Cotton Valley horizontal, #5H G.T. Waldrop Gas Unit, is in the Robert Wyatt Survey, A-728, Panola County, and had a 24-hour peak production rate of 4.1 million cu. ft. of gas per day from its site. The well was drilled to 13,475 ft. and bottomed to the southeast beneath the Charles Scruggs Survey, A-614.

3. In Section 20-14n-11w of Red River Parish, La., EnCana Corp. completed a horizontal Haynesville shale well as part of Red River-Bull Bayou Field. The initial daily potential for #1 Young Rex 28H is 20.45 million cu. ft. of gas and 364 bbl. of water through perforations at 12,686-16,095 ft. On a 22/64-in. choke, flowing casing pressure was 8,558 psi. The new producer was drilled to 16,197 ft., or a true vertical depth of 12,319 ft. Log tops at the site include Hosston at 6,525 ft.; Cotton Valley at 9,309 ft.; Bossier at 10,344 ft.; and Haynes­ville at 12,641 ft.

4. In Bossier Parish, La., Petrohawk Energy Corp. of Houston completed a horizontal Haynesville well as part of Elm Grove Field. Initial daily potential for the #1 Willis 36H et al was 19.12 million cu. ft. of gas and 617 bbl. of water daily through fracture-treated perforations at 11,865-16,430 ft. The flowing casing pressure was 7,602 psi on a 24/64-in. choke. The new producer was drilled to a total depth of 16,520 ft., 11,808 ft. true vertical, in Section 36-16n-11w.

5. Two horizontal Haynesville completions were reported from Caspiana Field in Caddo Parish, La., by Oklahoma City-based Chesapeake Energy Corp. The #1 Zimmerman 30-15-11H was tested flowing 19.1 million cu. ft. of gas and 82 bbl. of water per day through perforations at 12,095-16,063 ft. on a 22/64-in. choke. The new producer was drilled to a total depth of 16,154 ft., 11,915 ft. true vertical, in Section 30-15n-11w. In Section 19-15n-11w, Chesapeake’s #1 Ratzburg was drilled to 16,626 ft., 11,816 ft. true vertical, and had a daily flow rate of 17.57 million cu. ft. of gas and 134 bbl. of water through fracture-treated perforations at 12,002-16,541 ft. Flowing casing pressure was 7,952 psi on a 22/64-in. choke.

6. Questar Corp.’s #1 Sustainable Forest 29H was tested flowing at a daily rate of 25.05 million cu. ft. of gas and 895 bbl. of water through fracture-stimulated perforations at 12,460-16,872 ft. The horizontal Haynesville well is in Bienville Parish, La., in Section 29-15n-9w, and was drilled to 17,193 ft., 12,445 ft. true vertical. Flowing casing pressure was gauged at 5,297 psi on a 28/64-in. choke. Questar’s headquarters are in Salt Lake City.

7. Questar also completed another horizontal Haynesville well as part of Woodardville Field in Bienville Parish, La. The daily flow rate from #2 Jimmy Woodard was 23.77 million cu. ft. of gas and 120 bbl. of water daily through fracture-treated perforations at 12,180-16,651 ft. The well was tested on a 25/64-in. choke and the flowing casing pressure was 8,250 psi. Located in Section 34-15n-9w, the new producer was drilled to 16,775 ft., 12,215 ft. true vertical.

8. According to IHS Inc., Lafayette, La., independent Midstates Petroleum Corp. completed a directional Sparta Sand well in Pine Prairie Field. The #4 Arceus Guillory is in Evangeline Parish, La., and was tested pumping 343 bbl. of 39-degree crude and 280,000 cu. ft. of casinghead gas per day through perforations at 8,852-9,114 ft. It was drilled to a total depth of 9,355 ft., 9,345 ft. true vertical, in Section 36-3s-1w.

9. Wireline logs at McMoRan Exploration Co.’s Davy Jones prospect, #1 (ST) OCS G26013 on South Marsh Island Block 230, indicate 135 net ft. of hydrocarbon-bearing sands in four Wilcox sections of the Eocene/Paleocene: two zones contained a combined 90 net ft. of pay. The Eocene/Paleocene (Wilcox) suite of sands logged below 27,300 ft. appears to be of exceptional quality. The well was then drilled from 28,263 ft. to 28,603 ft. and wireline logs indicate an additional 65 ft. of hydrocarbon-bearing sands are present below the upper discovery. New Orleans-based McMoRan plans to deepen the well to 29,000 ft. and to conduct flow tests to confirm the ultimate hydrocarbon flow rates from the five separate zones. McMoRan operates the Davy Jones prospect and holds a 32.7 % stake. Other working interest owners are Plains Exploration & Production Co., with 27.7%; Energy XXI, with 15.8%; Nippon Oil, 12%; W.A. “Tex” Moncrief Jr., 8.8%, and a private investor who has 3%. The drilling rights to the 792-acre lease were originally purchased in March 2004.

10. Rooster Petroleum LLC of Houston completed a 12,451-ft. well in Eugene Island Block 28 Field. Drilled from an existing platform, #A-3 hit 30 net ft. of oil and gas pay in the Tex W sand. The initial test flow was 1,242 bbl. of crude and 5.16 million cu. ft. of gas per day. The new completion tested the updip attic potential of the Tex W sand that currently produces from #A-2 ST1. Through perforations at 11,948-57 ft., October production from the #A-2 ST1 was 2,523 bbl. of crude, 8.3 million cu. ft. of casinghead gas and 29,004 bbl. of water. The #A-2 ST1 and #A-3 are the only current producers in Block 28 field.

11. Houston-based Phoenix Exploration Co. LP completed a directional Belle Isle Field well in the Atchafalaya Bay area of St. Mary Parish, La. The #44 State Lease 00340 Atchafalaya Bay was tested flowing 5.01 million cu. ft. of gas and 22 bbl. of water daily through perforations in an unreported production zone at 14,530-44 ft. The respective flowing and shut-in tubing pressures were gauged at 3,760 psi and 4,307 psi. The new producer was drilled to 14,670 ft. in Miocene.

12. Miocene production was reported by Houston-based Dimensions Energy Co. LLC from Lake Hatch Field in Terrebonne Parish, La. The lateral, #58-D LL&EB, was tested in two Miocene zones; the first zone at 9,956-72 ft. flowed 150 bbl. of 35-degree crude and 172,000 cu. ft. of gas daily. On a 9/64-in. choke, flowing tubing pressure was 1,200 psi and shut-in tubing pressure was 1,500 psi. The second zone flowed 192 bbl. of 35-degree oil and 325,000 cu. ft. of gas per day through perforations at 10,348-60 ft. Respective flowing and shut-in tubing pressures were 1,320 psi and 1,600 psi. In Section 5-18s-16e, the dual producer was drilled to 10,560 ft., 10,020 ft. true vertical.