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Home My WebLink About199-068XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. / ~- (~ File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halfrnn~.~, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED Logs of various kinds Other COMMENTS: Scan ned 'by~x,~B.,ev_~eflpianna TO RE-SCAN Vincent Nathan Lowell Notes: Re-Scanned by; Be~edy Dianna Vincent Nathan Lowell Date: /si ., e e MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ßt1q S/lCtf û~ P. I. Supervisor 1 DATE: MaY8~~OO(o ,qq.O (gß FROM: John Spaulding, Petroleum Inspector SUBJECT: Location Clearances Pioneer Unit Pioneer Natural Res. The following wells in the Pioneer Unit were inspected for location clearances: Bering 03 PTD: 202-177 Baranoff 04 PTD: 202-178 Cook 01 PTD: 202180 Lowell 02 PTD: 202-179 1702-14CC PTD: 199-065 1702-15DA WDW PTD 199-064 1702-15DD PTD: 199-066 Cornhusker 04 PTD: 202-181 RL Smith 03 PTD: 202-182 DL Smith 01 PTD: 202-184 Stromberg 02 PTD: 202-183 vBi T 01 PTD: 199-068 ., ·M~,r"'n .:)\.iA, \:; 1"'- .L >::± All locations were found to be in excellent shape, well graded with some small amounts of debris. I requested that the debris be cleaned up and Joe Polya Pioneer Nat. Resources rep. agreed. He will inform as to when the final cleanup has been made so that I may make one last pass over the locations. SUMMARY; I found all locations in very good condition with small amounts of tidying up to be done. Attachments: photos on CD NON-CONFIDENTIAL e e Joe Polya Sr. Staff Drilling Engineer 700 G Street, Suite 600 Anchorage, AK 99501 Telephone: 907/343-2111 Fax: 907/343-2190 PIONEER NATURAL RESOURCES ALASKA. INC. October 17, 2005 Mr. Winton Aubert Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501-3539 C\"olotb \~ RE: Form 10-407 Completion Notices SCANNED DEC 1 92005 Pioneer Unit - P&A Coal Bed Methane Wells Dear Mr. Aubert, Please find attached 10-407 Completion Notices (in duplicate) to reflect plugging and abandonment operations for the following 13 wells located in the Pioneer Unit, Matanuska Susitna Borough, Alaska: · BL T#1 Well, · Pilot 1 consisting of the D.L. Smith #1, Stromberg #2, R.L. Smith #3 and Cornhusker #4 Wells, · Pilot 2 consisting of the Cook #1 , Lowell #2, Bering #3 and Baranof #4 Wells, · 1702-14CC, 1702-15DAand 1702-15DDWells, and Willow Fishhook #1 Well. This work was completed by Fairweather E&P Services, INC on behalf of Pioneer Natural Resources Company, Alaska. These reports should constitute the final correspondence from Pioneer Natural Resources Company, Alaska pertinent to this project. r~~- Joe Polya 700 G STREET. STE. 600 . ANCHORAGE. ALASKA 99501 . MAIN: (907) 277-2700 _ STATE OF ALASKA e ALASØ'OIL AND GAS CONSERVATION COMMISSION RECE'\/E WELL COMPLETION OR RECOMPLETION REPORT ANDct4>G?oo~ 1a. Well Status: Oil[J GasD Plugged 0 Abandoned 0 Suspended D WAG 0 1 b. Well Class: ~k 20AAC 25.105 20AAC 25.110 Develo~Sil' Ga$:~.tq,...¡~¡, "''''ii.m GINJD WINJD WDSPL 0 No. of Completions Other Service 0 StAWe~ß¡estD 2. Operator Name: 5. Date Comp., Susp., or 12. Permit to Drill Number: Pioneer Natural Resources Alaska, Inc. Aband.: Aug 19, 2005 .~,.- ,y~ 3. Address: 6. Date Spudded: 13. API Number: 700 G Street, Suite 600 Anchorage, AK 99501 July 31, 1999 50-009-20006-90/ 4a. Location of Well (Governmental Section): 7. Date TO Reached: 14. Well Name and Number: Surface: 793' FNL, 1333' FWL, Sec 22, T17N, R3W, SM August 17, 1999 BL T#1 ,-/ Top of Productive Horizon: 8. KB Elevation (ft): 15. Field/Pool{s): Same 130 Total Depth: 9. Plug Back Depth{MD+ TVD): Pioneer Unit Same Surface 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 534346 y- 2760240 (NAD 27) Zone- 4 6200 MD, TVD ADL 374124 TPI: x- same y- same Zone- 4 11. Depth Where SSSV Set: 17. Land Use Permit: Total Depth: x- same y- same Zone- 4 NA NA 18. Directional Survey: Yes o No D 19. Water Depth, if Offshore: 20. Thickness of Permafrost: NA feet MSL NA 21. Logs Run: 22. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT. GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 20 94 X-52 Surface 321 Surface 321 26 983 sx + 360 sx top job None 13.375 68 L-80 Surface 1700 Surface 1700 17.5 1400 sx None 9.625 47 L-80 Surface 4494 Surface 4494 12.25 1117 sx None 7 29 L-80 4324 6200 4324 6200 8.5 470 sx latex 2000 None .. 23. Perforations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) None 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED ~b 2086-2772 131 bbl Type I cmt squeezed below 2086' / ~a \D 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: I Gas-Oil Ratio: Test Period ... Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity - API (corr): Press. 24-Hour Rate ... 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None OR\G\ , ..~ t_ ^ /)",n,. t , Form 10-407 Revised 12/2003 CONTINUED ON ~EVERSE c::::f.< f(¡/jJV{ I)~ /O/I'.5r)5 ~ ~ 'i-\< 28. GEOLOGIC MARKE' 29. ,., FORMATION TESTS NAME ~lLf TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None·'. None 30. List of Attachments: Final Well Schematic, Operations Summary 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Printed Name: Joe Polva Title: Sr. Staff Drilling Engineer Signature: C:::Yr~}_ Phone: 907-343-2111 Date: ,oJ 1,/0 S" (' , \ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 e e Pioneer Natural Resources Alaska, Inc. Pioneer Unit BLT #1 Plug and Abandonment Operations Summary July 29, 2005 Bled 50 psi or less casing pressure to 0 through tree and 9-5/8 casing wing valve. Rigged up new 9-5/8 inch casing wing valve (2 inch, 3000 psi.) Rigged up circulating lines and returns tanle Circulated 25 bbl water (well returns from other jobs) down tubing and up 9-5/8 x 2-7/8 inch casing /tubing annulus. Pumped 3 bpm with very gassy returns. Shut in well for 15 minutes, 25 psi buildup. Bled off gas, shut in for 10 minutes, 20 psi buildup, circulated 5 more bbls water, small amount of gas in returns. Shut in well, 10 psi buildup after 20 min. SDFN July 30, 2005 Check well for pressure. Bled 20 psi or less casing pressure to 0 through 9-5/8 casing wing valve. Circulate 80 bbl fresh water down tubing and out 9-5/8 inch casing, some gas in returns. Shut in well. Well dead. Test casing to 1000 psi for 30 minutes, test good, no bleed off. Bleed casing down to O. Change out 4 inch port on wellhead to 4 x 2 inch bushing and bull plug from 4 inch valve. Set two way checks in dual tubing hanger. Check well for flow, no flow. Pull dual tree. Set 3000 psi WP BOP stack on 11 inch 3000 psi casing head. Rig up accumulator lines, function test blind rams. Test blind rams to 3000 psi, bleed off pressure. Test OK. Leave blind rams closed. SDFN July 31, 2005 Erected 3 sections of 10' x 5' x 10' scaffolding for working floor. August 1, 2005 Move cementing equipment from Pilot 1 area to BLT #1. Completed rig up of scaffolding. Spot crane. Moved in Pioneer horizontal tank: for flow volume. Rigged up flow lines and pump in line. Pressure tested BOP stack to 300 and 3000 psi. Test good. Rigged up tubing tongs. Held safety meeting for tubing work. Pull tubing hanger with 27K pull. LD landing joint and hanger joint. PU 2 joints 2-7/8 tubing, J into RBP. Pressure to surface, open 9-5/8 inch casing to flow tank:, well flowing water at 42 bph. Shut in casing pressure 350-380 psi. J offRBP. LD 1 joint tubing, pick up 2,4,6,8 and 10 foot pup joints to adjust top of tubing level on floor. J into RBP, flow well to tank: briefly, measure flow at 32 bph. Shut in well and perfonn injection test on perforations. Inject 20 bbl water at 3 bpm down casing, 1900 psi injection pressure. August 2, 2005 Move in 40 bbl batch unit. Stage circulating tank: and centrifugal pump, unload mud products, rig up mud mixing lines. Wait on polymer to be flown in from Kenai. Mix 5 each 40 bbl batches of 11.7 ppg mud and circulate mud at surface while mixing. Drive chain on 50 bbl batch mixer broke leaving only 40 bbl mixer for last part of job. Pump 200 bbl, 11.7 ppg mud down tubing with annulus shut in displacing mud below RBP. Chase mud with 7 bbl water to clear tubing. Pump pressure 1900 to 2150 psi. Monitor pressure bled off to 400 psi quickly while shut in, bled casing to 0, J off to close RBP, shut in well. Very little bar left in circulating tank: indicating good mud mix job. Crew worked until 12:30 -1:00 AM to finish pump job. - 1 - e e August 3, 2005 J into RBP. Casing pressure. at 125 psi. Mix and circulate 80 bbl, 11.7 ppg mud down tubing and up annulus. Well dead. Release slips on RBP. Pull10K to free tool, POOH, LD tubing and RBP. Rill with 2-7/8 inch tubing. Drop first two joints down hole. Rill with 50 joints tubing to 1550 feet. Shut in well, SDFN. August 4, 2005 Rill from 1550 to 2236 feet with 2-7/8 inch tubing open ended. Encounter obstruction. Detennine that previously dropped 2 joints of tubing are lodged in collapsed casing patch at 2245 to 2305 feet. Well file review indicates that casing patch was exposed to excessive differential pressure during swabbing and testing operations in January 2000. Wait on orders for change in cementing program. Receive verbal approval for proposed change from Winton Aubert at AOGCC. Pull up to 2201 feet tubing depth to accommodate working level on rig floor. Pump 13 bbl water spacer down tubing saving mud returns for later displacement. 'Mix 85 bb115.1 ppg, Type I cement and pump down tubing with casing and pipe rams shut in. Pump pressure 1700 psi at 3 bpm. Chase cement with 5 bbl water and 12 bb1 mud. Pressure rose to 2400 psi on last 3 bbl of displacement. Pump 3.5 bbl mud down casing to clear tubing of any cement, shut in well at 1500 psi. Clean up equipment. August 5, 2005 Safety meeting. Check well, 400 psi on casing, 0 psi on tubing. Bleed off casing. Pull 42 K on tubing, no go. Pressure test 9-5/8 inch casing to 1150 psi. Test good. Continue to work pipe with up to 65K pull, only 5 inches of movement. Not able to circulate down tubing. Call out Pollard for tubing cut. Rigged up Pollard slickline unit and lubricator. Rill with 2.25 inch OD tubing cutter, could not get past 120 feet due to thick mud in tubing. Try 2.125 inch OD charge, no go as well. Order out more sinker bars and 1-9/16 inch OD tubing punch. SDFN 11 :00 PM. August 6, 2005 Safety meeting. Pick up additional sinker bars to 500 Ib total, RI 2-7/8 inch tubing to 1000 feet. POOH and pick up tubing punch and Rill with 500 Ib sinker bars. Work tools overnight, unable to get below 1520 feet. August 7, 2005 Safety meeting. Pressure test annulus and establish injection down 2-7/8 x 9-5/8 inch annulus at 1 to 2 bpm at 1900-2100 psi. Consult with AOGCC for alternate cementing procedure and receive verbal approvaL Punch tubing at 1520 feet, pull lubricator and LD gun. RU cementing lines on 2-7/8 inch tubing and pump 5 bbl water to verify ability to circulate up 2-7/8 x 9-5/8 inch annulus. Shut in annulus and pump 5 bbl water down tubing. Mix and pump 46bbl cement down tubing and squeeze into: 9-5/8 x 2-7/8 inch annulus and perforations at 2086 feet and below. Pump rate 1 to 1.5 bpm, 1900-2100 psi pump pressure. Displace cement down tubing with 14 bbl water, shut in well, clean up equipment. SDFN August 8, 2005 Safety meeting. Check welL SICP 300 psi, SITP 300 psi. Pressure test squeeze plug to 1500 psi for 10 minutes, test good, no leakoff. Displaced gel mud in 2-7/8 x 9-5/8 inch annulus with 40 bbl water followed by 65 bbl15 ppg Type I balanced cement plug set from 1520 to 620± feet in tubing and casing. Rig up Pollard and APRS, cut tubing at 610 feet. POOH with wireline and - 2 - - e release Pollard. POOH with tubing. Pick up Halliburton 4-5/8 inch perforating gun, RllI on tubing to 585 feet. Close pipe rarns, pressure up to 1300 psi to fire gun on 5 minute delay. Tubing joint slipped up hole 30 feet to next collar in pipe rarns. Wait for firing head delay 5 minutes, perforate 9-5/8 and 13-3/8 inch casings from 555 to 565 feet. Bleed off gun gas, POOH with tubing and gun. SDFN August 9, 2005 Safety meeting. Establishinjection down 9-5/8 inch casing at 2 to 2.5 bpm at 500 psi. Rig down BOP stack and scaffolding. Insert bottom wiper plug in 9-5/8 inch casing, rig up wellhead tree. Mix and pump 65 bbl 15 ppg Type I cement down 9-5/8 inch casing and squeeze 24 bbl cement through perforations into 9-5/8 x 13-3/8 inch annulus. Injection pressure of 700 psi with final squeeze pressure of 1200 psi. Shut in well. Move to 1702-15DD well. SDFN August 10, 2005 Check well, 400 psi on 9-5/8 inch casing. Bleed off pressure. August 16, 2005 Cut off well 8 feet below grade. Cement to surface in all casings. August 18, 2005 Chuck Sheve of AOGCC inspected well for final P&A. August 19, 2005 Welded marker plate on well. Backfill of excavation to be completed upon removal of surface equipment. - 3 - Pioneer Natural Resources Alaska, Inc. BL T PI Abandonment Photos Photo 2: Pulling tubing and retrievable bridge plug. - 4- Photo 3: Laying down retrievable bridge plug. - 5 - Photo 4: BLT #1 well cut off. Photo 5: BLT#1 well with marker plate installed. - 6- Pioneer Unit Bl T #1 Final Well Schematic 19 17 BLT#i API 50-009-20006-90 r Sec 22 Pioneer Natural Resources Alaska, Inc. 17N Rng 3W . I Size 1 Weight I Grade Thread County Matanuska,Susitna State Alaska 68 p f Field Pioneer Unit Country USA 7 ~L OD ID 3 , 214 5796' I I 5796·5810, ~ ·59 5785' 5180'·5716' 5180- I 5264 5552 - 5606 - 5642 - 5650, 5668 - 5672, 5707 - 5716 =1= 5160 3 CICR@ 5160' 4813 330 4813' - 4813· ~5024 -~052. :60 - 5146 7 , 8 9 ~ P@4096' ~ 10 38 ==f 13902' - 3940' perf 5 spf alpha jet, _ 3902 - 390B. 3 3840 valve in place 2732 40 .SPf alpha iet, 135/45 phasing 50 2250' - 2300' perf 5 spf alpha jet, 135/45 phasing 32 Gram .45" holes. 60 14 ~ 1 10 Perforations 1 ~ :@ perforations 18 Fish, 2 jts 2-7/8 inch tubing, dropped in hole, stuck in collapsed casing patch 19 t80-1800 Well cuttoff 5 fee~ 20 Top of cement behind ~ i R I : 1:::: Created b STG 3/ 4/04 Modified by JRM 9/24/05 y 16 PBTD 6105 e e MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg, P. I. Supervisor /~---~ <;:rf¿ï [ ! r> { \ .___' "j l f "2.~rl""" ( \ t~] '-'.> DATE: August 18,2005 FROM: Chuck Scheve, Petroleum Inspector SUBJECT: Surface Abandonment Pioneer Unit Willow Fishhook #1 PTO# 203-207 1702 14CC PTO# 199-065 1702 150A-WO PTO# 199-064 1702 1500 PTO# 199-066 BL T-01 PTD# 199-068 Thursday, Auaust 18,2005: I traveled to Pioneer's Coal Bed Methane exploratory locations to inspect the casing cut off and abandonment of the above listed wells. All casing strings on the above listed wells were cut off at approximately 5' below original ground level. All 5 wells were found full of cement to within 18" of surface in all strings and will be topped off prior to installation of the marker plates. The marker plates with the required information bead welded to them were on location and will be welded to the outer mqst casing. SUMMARY: I inspected the casing cut off depth, cement to surface and the P&A marker plates on the \Willow Fishhook #1, BL T-01, 1702 14CC, 1702 150A-WO and 1702 1500 wells and found all to be in order. Attachments: Willow Fishhook #1.JPG 1702 14CC.JPG 1702 150A-WO .JPG 1702 15 DO .JPG BL T-01. JPG ~CANN\E.t) 2) 1 2DD~ 1,,1 Pioneer ¡ 702 ¡ Cement to Surface 2 Pioneer! 702 ¡ 3 ) (qq-Ob£J ) Subject: BL T#1 cementing modifications. From: Jesse Mohrbacher <jesse@fairweather.com> Date: Sun, 07 Aug 2005 11: 12:00 -0800 To: Winton Aubert <winton_aubert@admin.state.ak.us> CC: "Polya, Joe" <Polyaj@ploneernrc.com> Bill Penrose <bill@fairweather.com>, Tisch Richard <richard@falrweather.com> Hi Winton, Thank you for taking my call this Sunday morning. Per our previous conversation this morning, we are proposing another modification to the BL T#1 P&A cementing program. As we discussed, we have 2-7/8 inch tubing cemented in the well at 2200 feet, the result of a squeeze job on the lower zones. Due to the heavy mud in the tubing, we can not get below 1520 feet with a tubing punch even though we have doubled up on the sinker bars on the eline to 500#. We can pump down the 2-7/8 x 9-5/8 annulus into the top perforations at about 1900 psi. Our plan is to perforate the tubing at 1520 feet and establish injection down the tubing and the 2-7/8 x 9-5/8 inch annulus to ensure that we can squeeze cement away. We will then squeeze 46 bbl cement down the tubing and down the 2-7/8 x 9-5/8 annulus below 1520 into the perforations. The cement will be chased with water which will clear the tubing and leave the cement level at about 1600 feet, almost 500 feet above the top perfs. The well will be shut in and the plug will be tested to 1500 psi after waiting overnight on cement. The tubing will then be cut at 1520 feet and a balanced plug will be laid in the 9-5/8 casing from 1520 (or lower if possible) to 1200 feet. Alternatively, the plug could be set through the perforations in the tubing and up the tubing/casing annulus and the tubing cut at a shallower depth. Then we will proceed with perforating the 9-5/8 and 13-3/8 inch casings at 500 feet and squeeze the 13-3/8 x 9-5/8 annulus and set the surface plug at the same time. This plan does not call for total cement from 1520 to surface in the 9-5/8 inch casing and while this is possible, we don't believe it is necessary. Please contact me on my cell phone at 281-413-8007 with any questions or comments as we are proceeding ahead with this plan for final P&A. Regards, Jesse Mohrbacher ,.·.··'f'·j1l..NNI Er-,.I ~u G Oq 2005 -',)\,,1 "!.œ ~, ~,.. ;:-\- tè. Fairweather E&P Services, Inc. 2000 East 88th Avenue, Suite 200 Anchorage, AK 99507 907 -258-3446 650 N Sam Houston Pkwy E, Suite 505 Houston, TX 77060 281-445-5711 ) ) S.µbjec': ".f\11ßr8~t~·.·9.~.~~·8~i8.9 ··f·nø..·p~.a.·..~rQçe9.u.~e··f?r·..BLor#1 Fr~m:. Jfi)ss~·;~o~rÞ~9~~r<::jes~~~f~i(\ðleather~cQm:>······ D~Je:. Thu, ·()4.~Y949Q5·1q: 15:t5-QßQQ' Hi Winton, thank you for consulting with me earlier today regarding the BL T#1 well and for providing a verbal go ahead for a modified P&A cementing procedure. Please find attached our proposed alternative cementing procedure that has been necessitated by what we believe to be a collapsed casing patch at about 2250-2300 feet. Please contact me with any questions regarding this proposed alternative program. Regards, Jesse Mohrbacher Fairweather E&P Services, Inc. 2000 East 88th Avenue, Suite 200 Anchorage, AK 99507 907 -258-3446 650 N Sam Houston Pkwy E, Suite 505 Houston, TX 77060 281-445-5711 Content-Type: app'ication/pdf BL T#1 Well bore Diagram current Aug 4, 2005.pdt Content-Encoding: base64 BL T#1 Wellbore Diagram Alt Proposed Aug 4, Content-Type: application/pdf Content-Encoding: base64 Content-Type: application/pdf alternate cementing procedure. pdt Content-Encoding: base64 ) ) Pioneer Natural Resources Alaska, Inc. BL T #1 Alternative P&A Cementing Procedure August 4, 2005 The BL T #1 well is currently being plugged and abandoned by Pioneer Natural Resources, Inc. After killing the well and pulling a retrievable bridge plug from 1104 feet, an obstruction in the 9-5/8 inch casing has been discovered at 2250± feet. The obstruction is believed to be a collapsed casing patch. The well is presently dead with 11.7 ppg mud in the hole from surface to 3840 feet. The following alternate cementing procedure is proposed for plugging the BL T # 1 well now that it is not possible to run to bottom at 3840 feet. Attachments 1 and 2 show the current (August 4, 2005) and proposed P&A wellbore diagrams. 1. With open ended tubing to 2201 feet, pump 5 bbl water spacer then squeeze 85 bbl 15 ppg Type I cement down tubing. 2. Clear tubing with 13 bbll1.7 ppg mud. Shut in well. Wait at least 30 minutes for injection pressure to bleed down, bleed off any pressure and pull up 3 to 5 joints of tubing, Shut in well. WOC at least 4 hours. 3. RIH to 2200. Set a balanced cement plug (15 ppg, Type I) from 2200 to 1600 feet. POOH. Shut in well. WOC 12 hours. 4. Test cement plug in 9-5/8 inch casing to 1125 psi. 5. Rig up firing head and 4-5/8" millennium perforating gun, 5spf, 60 degree phasing, 50 shots total. Follow all safety protocols as directed by Halliburton perforating hand. 6. Run perforating gun to 500 feet pushing a 9-5/8 inch wiper plug (top plug, solid type) ahead of gun. Place 1500-2000 psi on casing to fire gun. Bleed off any gun gas out 9-5/8 inch casing valve. POOH with tubing and perforating gun. 7. Inject 20 bbl water spacer down 9-5/8 casing. Insert 9-5/8 wiper plug (bottom type) in casing. 8. Mix and pump 65 bbl cement down casing, squeezing perforations. Leave 13-3/8 x 9-5/8 inch annulus open at surface and monitor for any flow (Flow is unlikely, annulus was cemented from 250 to surface by ARCO in 1992). 9. Chase cement with 0.5 to 1 bbl water to flush lines and BOP stack. 10. Shut in well. WOC 12 hours. 11. Dig out cellar, cut off wellhead. After AOGCC inspection, install marker plate and backfill excavation. J ) Attachment 1: Pioneer Unit BL T #1 Current Well Schematic L J 17 ~~ ~~:#1 See Rng API 22 3W 50-009-20006-90 Pioneer Natural Resources Alaska, Inc. County Matanuska,Susitna Field Pioneer Unit State Alaska Country USA 16 No. I Depth I Length I 00 I 10 Â lib. 1 6105 3 2 5796 214 11.7 ppg mud 311 1I§15 3 5785 3 4 5180 536 ~ co/sed~ii 311 1I§12 5 5160 3 6 4813 330 11 7 4755 3 §II lIE 1 0 8 4324 9 4096 3 10 3902 38 11.7 ppg mud 11 3840 12 2732 40 13 2250 50 9 14 2245 60 15 2086 14 8 16 1104 17 250 2 18 2250± 62 ~ ~ PBTD 6105 7 6 5 4 3 2 1 Created by STG 3/24/04 Size Weight Grade Thread Depth Casing 20 94 H40 STC 321 Casing 13-3/8 68 ppf L80 BTC 1700 Casing 9-5/8 47 ppf L80 BTC 4494 Casing 7 29 ppf L80 LT&C 6200 Tubing 2-7/8 6.5 J55 8RD 1073 Description CICR @ 6105' 5796' - 6010 perf 5 spf alpha jet 5796 - 5810,5822 - 5830,5844 - 5868 5888 - 5900, 5963 - 5994, 6004 - 6010' CICR @ 5785' 5180' - 5716' perf 5 spf alpha jet 5180-5188,5198 - 5219,5236 - 5248 5264 - 5329, 5360 - 5362, 5378 - 5388 5406 - 5408, 5436 - 5468, 5518 - 5527 5552 - 5578,5606 - 5608,5620 - 5630 5642 - 5650, 5668 - 5672, 5707 - 5716 CICR @ 5160' 4813' - 5146' perf 5 spf alpha jet 4813 - 4874,4928 - 4954,4970 - 4990 5024 - 5052,5060 - 5146 CICR @ 4755' Top of Liner @ 4324 CIBP @ 4096' 3902' - 3940' perf 5 spf alpha jet, 135/45 phasing 32 Gram .45" holes. 3902 - 3908,3913 - 3940 Packer with flapper valve in place 2732' - 2772' perf 5 spf alpha jet, 135/45 phasing 32 Gram .45" holes. 2250' - 2300' perf 5 spf alpha jet, 135/45 phasing 32 Gram .45" holes. Weatherford csg patch from 2245' - 2305' (collapsed) 2086' - 2100' perf 5 spf alpha jet, 135/45 phasing 32 Gram .45" holes. Baker A3 lockset RBP, running tool on tubing above perforations for surface plug in 1992 Fish, 2 jts 2-7/8 inch tubing, dropped in hole, stuck in collapsed casing patch Modified by JRM 8/04/05 J ) Attachment 2: Pioneer Unit BL T #1 Proposed Final Well Schematic BOC 500' 11.7 ppg mud TOC-1600' BOC-3360' '1f~"';1~~"'~~~ifn .~~',~..":",:,,.,:.,.:ì:,::I1 11 38 -~~ 1iiE10 11 .7 ppg mud ~ & PBTD 6105 19 Well BL T #1 17 Qtr/Qtr See Twp 17N Rng County Matanuska,Susitna Field Pioneer Unit 16 API 50-009-20006-90 22 Pioneer Natural Resources Alaska, Inc. 3W State Alaska Country USA No. I Depth I Length I 00 I 10 1 6105 3 2 5796 214 3 5785 3 4 5180 536 14 13 9 5 5160 3 6 4813 330 7 4755 3 8 4324 9 4096 3 10 3902 38 11 3840 12 2732 40 13 2250 50 14 2245 60 15 2086 14 17 250 2 18 2250± 62 19 Surface 20 1780-1800 8 7 6 5 4 3 2 1 Created by STG 3/24/04 Size Weight Grade Th read Depth Casing 13-3/8 68 ppf L80 BTC 1700 Casing 9-5/8 47 ppf L80 BTC 4494 Casing 7 29 ppf L80 LT&C 6200 Tubing Description CICR @ 6105' 5796' - 6010 perf 5 spf alpha jet 5796 - 5810,5822 - 5830, 5844 - 5868 5888 - 5900, 5963 - 5994, 6004 - 6010' CICR @ 5785' 5180' - 5716' perf 5 spf alpha jet 5180-5188,5198 - 5219,5236 - 5248 5264 - 5329, 5360 - 5362,5378 - 5388 5406 - 5408,5436 - 5468,5518 - 5527 5552 - 5578, 5606 - 5608, 5620 - 5630 5642 - 5650, 5668 - 5672, 5707 - 5716 CICR @ 5160' 4813' - 5146' perf 5 spf alpha jet 4813 - 4874, 4928 - 4954, 4970 - 4990 5024 - 5052, 5060 - 5146 CICR @ 4755' Top of Liner @ 4324 CIBP @ 4096' 3902' - 3940' perf 5 spf alpha jet, 135/45 phasing 32 Gram .45" holes. 3902 - 3908, 3913 - 3940 Packer with flapper valve in place 2732' - 2772' perf 5 spf alpha jet, 135/45 phasing 32 Gram .45" holes. 2250' - 2300' perf 5 spf alpha jet, 135/45 phasing 32 Gram .45" holes. Weatherford csg patch from 2245' - 2305', collapsed 2086' - 2100' perf 5 spf alpha jet, 135/45 phasing 32 Gram .45" holes. perforations for surface plug in 1992 Fish, 2 jts 2-7/8 inch tubing, dropped in hole, stuck in collapsed casing patch Well cuttoff 5 feet below ground level. Top of cement behind 9-5/8 inch casing Modified by JRM 7/19/05 ("";;'~ if' ~ :!,;;~ :--. ~,:I¡ !.Il,:: !b~ , ' ", iI' \ I I "" ¡: i1J\~: t, ~u¡n1JL.6 ~ ~fb .' n\: !,,!:J: ;,:,!' 1 ¡ :/ '. ¡ ! : :U1 · ~I'" ,r\ '""11 /ï"':ï ~ '·n' .r¡ jr:;l I ."~ ". i:1 :,,.1 ~ :¡., w ' : ~ ..' ,:~" l.~ \. ;.] , jj '\ \'\ 1 :~( .,' A. \ '\ :; ¡ ~ '1'""1'~) I '¡ \ . U ' /:'1.\ !,I L¡.¡~ì \ U ¡U',,\ 11'ï'1\ ~ ,w '--'.!..oJ W \..:::...J'I . ,:-.:\:..¡¡ !...~ ~ ! / / l ;' I j / FRANK H. MURKOWSKI, GOVERNOR AlfASIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. "JTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Joe Polya Senior Staff Drilling Engineer Pioneer Natural Resources Alaska, Inc. 700 G Street, Suite 600 Anchorage, Alaska 99501 " ' ,.' " ". ç., (>') ('i n 1=, c·,ti·"I,NNEL¡ ~ U l l, ~.~ L.'·" ~Yr ,~"., ".." ~"' d;'lrJ~ ,tfI;". ",:' ,', -.;::,,,;,;,v ' t~l' . Re: Pioneer BLT #1 Sundry Number: 305-205 Dear Mr. Polya: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on iday or weekend. A person may not appeal a Commission decisio to S' perior Court unless rehearing has been requested. ~ DATED thiS~y of July, 2005 Encl. Joe Polya Sr. Staff Drilling Engineer 700 G Street, Suite 600 Anchorage, AK 99501 Telephone: 907/343-2111 Fax: 907/343-2190 July 26, 2005 Mr. Winton Aubert Alaska Oil and Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, AK 99501-3539 RECEIVED JUL 2 6 2005 Alaska Oil & Gas C on$. Commission Anchorage RE: Sundry Approval Applications (Form 10-403) Pioneer Unit - P&A Coal Bed Methane Wells Dear Mr. Aubert, Please find attached Applications for Sundry Approvals (in duplicate) for the following three wells located in the Pioneer Unit, Matanuska Susitna Borough, Alaska: . The BL T#1 Well and the . 1702-15DA Well. These are the final two of thirteen sundry applications Pioneer is submitting. Pioneer has awarded the contract for this work to Fairweather E&P Services, INC. Fairweather has had to adjust the proposed timing for BL T#1 due to equipment availability; therefore, Pioneer requests that the BL T#1 sundry review be expedited and approved bv Thursday, Julv 28 if at all possible. Thank you for your assistance in this matter. Respectfu lIy, Joe Polya ORIGINAL ~: July 25, 2005 RECF/vcl) JUl 2 6 200.5 Ar~'kl Oil & Gas \¡').I' , . ~...,. "" ~"~''¡~'¡¡~;SiOn Anchofsga Mr. Winton Aubert Alaska Oil and Gas Conservation Commission 333 W. 7th Ave #100 Anchorage, Alaska, 99501-3539 RE: Sundry Approval (Form 10-403) Pioneer Unit - BL T #1 Well Plug and Abandon Dear Mr. Aubert: Attached is the 10-403 form requesting approval to Plug and Abandon the BL T #1 well. Pioneer Natural Resources acquired the Pioneer Coal Bed Methane Project through the acquisition of Evergreen Resources Corporation. Evergreen's predecessor in the Pioneer Unit, Ocean Energy, attempted various stimulation techniques in an effort to produce methane from this well; however, the well did not prove economical. Pioneer has determined that this project is not / economically feasible at this time based on a thorough evaluation which included peer assists with experts involved in the profitable coal bed methane projects in Colorado and Canada. Pioneer plans to plug the well according to the enclosed P&A procedure. If you have any questions, please feel free to' contact me at 907 -343-2111 or polyaj@pioneernrc.com. Sincerely, Joe Polya Sr. Staff Drilling Engineer Pioneer Natural Resources Alaska, Inc. 700 G Street, Suite 600 Anchorage, AK 99501 If',), ~ i\1 ^ L _ ~ ~ \. /"'0\ : STATE OF ALASKA £>-is 7 I". 7/5 ALA~ A OIL AND GAS CONSERVATION COMM,_.:»ION APPLICATION FOR SUNDRY APPROVAL / 20 AAC 25.280 Abandon L::.J Suspend U Operational shutdown U Alter casing D Repair well D Plug Perforations D Change approved program D Pull Tubing D Perforate New Pool D 2. Operator Name: 4. Current Well Class: Development [B" Stratigraphic D CfJr 7'" Z, 7.; 0'5 \.4 l'1 J'r 'L( rl..L'v~ R~eei\/~D JUL 2 6 2005 1. Type of Request: Perforate U Alaska OO~iwCons, t,;ommaHli!J Stimulate D Time Extensi~riCBorage Re-enter Suspended Well D 5. Permit to Drill Number: Pioneer Natural Resources Alaska, Inc. "-'£ík'" Exploratory -0- 199-068 ,/ D 6. API Number: Service 3. Address: 700 G Street Suite 600 Anchorage, AK 99501 7. KB Elevation (ft): 104' KB (4' AGL) 8. Property Designation: ADL 374124 11. 50-009-20006-90-00 / 9. Well Name and Number: BL T #1 / 10. Field/Pools(s): Pioneer Unit PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 6200' MD 6200' MD 4092' TVD 4092' TVD CIBP @ 4092' MD NONE Casing Length Size MD TVD Burst Collapse Structural n/a n/a n/a n/a n/a n/a Conductor 321 feet 20.000 inches 321 feet 321 feet 1530 psi 520 psi / Surface 1700 feet 13.375 inches 1700 feet 1700 feet 5020 psi 2260 psi ",/ Intermediate 4494 feet 9.625 inches 4494 feet 4494 feet 6870 psi 4750 psi / Production o feet 0.000 inches o feet o feet o psi o psi Liner 1876 feet 7.000 inches 6200 feet 6200 feet 8160 psi 7020 psi /" Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 2086-3940' MD 2086-3940' MD 2.875 J55 1073 Packers and SSSV Type: Baker A3 Lockset @ 1104' 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program D BOP Sketch 0 14. Estimated Date for/,. ' - ') Commencing Operations: (7/28/~J¡(f5 16. Verbal Approval: Date: . Packers and SSSV MD (ft): Baker A3 Lockset @ 1104' / 13. Well Class after proposed work: ï,.J6k D Exploratory ~ Development [Y( Service D 15. Well Status after proposed work: Oil D Gas D Plugged 0 Abandoned 0 WAG 0 GINJ D WINJ 0 WDSPL D Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Joe Polya Printed Name Joe Polya Title Sr. Staff Drilling Engineer Signature Phone 907-343-2111 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: .3 e:> ç - .;:J 0 ð' Plug Integrity D BOP Test ~ Mechanical Integrity Test D Location Clearance ~ Other:\f,S t- Bop E \ +0 šooo pk '. Appro RBDMS BFl ~lUl 2 8 2005 (l '"..'; IJ ~ L Date: 1ft ID( COMMISSIONER APPROVED BY THE COMMISSION Form 10-403 Revised 11/2004 Submit in Duplicate l~' Il Pioneer Natural Resources Alaska, Inc. Plug and Abandon Procedure Pioneer Unit ARCO BLT#l Well The ARCO BL T # 1 well was drilled in 1992 by ARCO Alaska, Inc. as an exploration well to 6200 feet then P&A'd after testing multiple zones below 4800 feet. In 1999, Ocean Energy became the operator of the Pioneer Unit. Ocean Energy reentered the BL T # 1 well and performed a variety of production tests on the well through perforations in the 9-5/8 inch casing from 2086 to 3940 feet to evaluate coal bed methane potential in the well. In early 2000, Ocean Energy suspended the well prior to Evergreen Resources, Inc. becoming the Unit operator. Pioneer Natural Resources Alaska, Inc. (Pioneer) has now succeeded Evergreen as operator of ~/' the Pioneer Unit and has elected to P&A the ARCO BL T#1 well. The well has a 20 inch conductor set at 321 feet followed by 13-3/8 inch surface casing set at 1700 feet, 9-5/8 inch production casing set at 4494 feet and a 7 inch liner l1ung from 4324 to ("" 6200 feet. The TOC for the 9-5/8 inch casing is reported to be 1880 feet. 'During the original P&A, ARCO Alaska, Inc. perforated the 9-5/8 inch casing at 250 feet and circulated a surface cement plug in the 9-5/8 inch casing and 13-3/8 x 9-5/8 inch annulus after being unable to inject into the 13-3/8 x 9-5/8 inch annulus with 4000 psi surface pressure. The current configuration of the well has a Baker A3 Lockset retrievable bridge plug (RBP) is set at 1104 feet with 2-7/8 inch tubing hung off above the RBP at 1073 feet and the RBP running tool is reportedly hanging on the end of the tubing. A current schematic for the BL T# 1 well is presented in Attachment 1. Pioneer proposes the following P&A procedure to plug the well in accordance with AOGCC regulations. The proposed final wellbore schematic is provided as Attachment 2. 1. Verify all permit paperwork is in place and give AOGCC 24 hour notice of intent to r" begin well work operations and intent to cement well and give AOGCC representative chance to witness same. 2. Mobilize all necessary personnel and equipment to the location. 3. Check p~essure on 9-5/8 in~h casing and 13-3~8 x 9-5/8 in?h annul~ls. ~leed off to open /"" top tank If necessary. IE. M.. <> u. r ~, ~. (.1 fl ",,"ld I ~A./ e...,( I ~ I.fLt c;, u r tel c...Q , ~ ~It / 4. Install two-way check in tubing hanger. Have 2 each 2-7/8 inch and 1 each 2-3/8 inch two-way checks available for dual hanger. 5. Rig up 50 ton crane adjacent to well. .,r/ 6. Remove dual tree on top of 3000 psi B section of wellhead and install an 11 inch 3000 psi ,/ WP BOP stack (blind, pipe, annular) with accumulator. Pressure test stack to 3000 psi. / 7. Test 9-5/8 inch casing to 1000 psi. Note: Ocean Energy previously tested the unperforated 9-5/8 inch casing to 1000 psi from 284 feet to surface and from 4092 feet to / b1t#l PA procedure.doc Page 1 7/26/2005 8. 9. 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. surface. In both cases, the tests were run for 30 minutes and resulted in minor losses of test fluid on the order of 0.25 to 0.3 bbl over 30 minutes. Rig up scaffolding around well. Rig up tubing tongs, base plate (false rotary), bowl and slips on top of BOP stack. Pull tubing hanger and lay down tubing hanger joint. Inspect top joints of tubing for ./" integrity. RIH with tubing and running tool. Lightly close annular preventer. J into RBP, pickup 2000 to 5000 lb over tubing weight. RBP has bypass port that should open when RBP is pulled on. Monitor 9-5/8 inch casing for flow from possible pressure below RBP. If any flow or pressure is detected, close annular and bleed pressure to tank out 9-5/8 inch casing valve. Lightly close pipe rams to hold tubing down in case any additional pressure is trapped below RBP. Put 10 right hand rotations on tubing. Monitor 9-5/8 inch casing for flow. ,r'"'''''''' /,,,, ,/' Pull RBP from well. Do not exceedßt),09.-Q'1b pull on 2-7/8 inch EVE J55 tubing. LD 2- .-" 7 /8 inch tubing. l.".,.'''-/ Establish injection using formation fluids from well or cement rinsate from previous operations. Inject minimum 50 bbls fluid to ensure adequate injection capability into ",." perforations. Insert bottom wiper plug in 9-5/8 casing below 9-5/8 inch casing wing valve on wellhead. Close blind rams. Mix and pump 155 1, Type I, 15 ppg cement down 9-5/8 inch casing. After cement pumped, insertc wiper plug if no pressure remains on 9-5/8 inch c~1:ñgì(well will likely be ~iic or on vacuum). Displace cement with 139 bbl premixed ~?~ppg mud to 1900 feet. Shut in well. WOC. "..~".,'" Test plug to 1 000 psi surface pressure on 9-5/8 inch casing. Rig down scaffolding and BOP stack. Set a cement wiper plug in the 9-5/8 inch casing at 165 feet below ground level. RIH with cementing hose. Mix and set a 15 ppg, Type I cement plug in the 9-5/8 inch casing from 165 feet to .--/ surface. Excavate and remove cellar exposing casing. Rig up guillotine saw and cutoff wellhead a minimum of 5 feet below original ground level or below grade, whichever is deeper. b1t#l PA procedure.doc Page 2 7/26/2005 ~ 22. If necessary, perform top job on 13-3/8 x 9-5/8 inch annulus. Weld marker plate on well /' and backfill same. Pickup and debris and demob location. blt#l PA procedure.doc Page 3 7/26/2005 I I L L -" /' ", '" Pioneer Natural Resources Alaska, Inc. BL T# 1 Well Abandonment BOP Schematic .". C~al1'ler'O:l1 11 ,:;, 3M \'le11he.acl BSlect~QIl iþ 11 '.,," "",", I' '11 ~~, ~':\ ,r 'D' r::-"A ,! ',., :'.111" ' X,', , .. ,:n.!ji~J.., ,,:J\,' '-, I Shaffer 11 :::: 51\,1 Double: Gate:: B·]i:nd R.tams I ~ Sh3!ffer 11::~ 51\·1 Double Ga:te:: Pipe Rams ~ H)~dril 11':~ 51vl .A.llnular Preve.nter / L ,I ,,:1' , ( Pioneer Unit BL T #1 Current Well Schematic /' ~- ~ ,~ ~ Attach ment 1 : \'if Well BL T #1 ~ // Qtr/Qtr ~ 17 Twp 17N API 22 3W 50-009-20006-90 Pioneer Natural Resources Alaska, Inc. See Rng County Matanuska,Susitna State Alaska Field Pioneer Unit Country USA -- 16 No. I Depth I Length I 00 I 10 .... ~ 1 6105 3 2 5796 214 3 5785 3 4 5180 536 . ~ PBTD 6105 5 5160 3 6 4813 330 7 4755 3 8 4324 9 4096 3 10 3902 38 11 3840 12 2732 40 13 2250 50 9 14 2245 60 15 2086 14 8 16 1104 17 250 2 7 6 5 4 3 2 1 Created by STG 3/24/04 Size Weight Grade Thread Depth Casing 20 94 H40 STC 321 Casing 13·3/8 68 ppf L80 BTC 1700 Casing 9·5/8 47 ppf L80 BTC 4494 Casing 7 29 ppf L80 LT&C ~~ Tubing 2-7/8 6.5 J55 8RD Description CICR @ 6105' 5796' - 6010 perf 5 spf alpha jet 5796 - 5810,5822 - 5830,5844 - 5868 5888 - 5900,5963 - 5994,6004 - 6010' CICR @ 5785' 5180' - 5716' perf 5 spf alpha jet 5180-5188,5198 - 5219,5236 - 5248 5264 - 5329,5360 - 5362,5378 - 5388 5406 - 5408,5436 - 5468,5518 - 5527 5552 - 5578,5606 - 5608,5620 - 5630 5642 - 5650,5668 - 5672,5707 - 5716 CICR @ 5160' 4813' - 5146' perf 5 spf alpha jet 4813 - 4874,4928 - 4954, 4970 - 4990 5024 - 5052,5060 - 5146 CICR @ 4755' Top of Liner @ 4324 CIBP @ 4096' 3902' - 3940' perf 5 spf alpha jet, 135/45 phasing 32 Gram .45" holes. 3902 - 3908, 3913 - 3940 Packer with flapper valve in place 2732' - 2772' perf 5 spf alpha jet, 135/45 phasing 32 Gram .45" holes. 2250' - 2300' perf 5 spf alpha jet, 135/45 phasing 32 Gram .45" holes. Weatherford csg patch from 2245' - 2305' 2086' - 2100' perf 5 spf alpha jet, 135/45 phasing 32 Gram .45" holes. Baker A3 lockset RBP, running tool on tubing above perforations for surface plug in 1992 Modified by JRM 7/19/05 ( { Attachment 2: Pioneer Unit BL T #1 Proposed Final Well Schematic /- .... ~ . . PBTD 6105 18 Well BLT#1 17 Qtr/Qtr Twp 17N 16 County Matanuska,Susitna Field Pioneer Unit Sec Rng API 22 3W 50-009-20006-90 Pioneer Natural Resources Alaska, Inc. State Alaska Country USA No. I Depth I Length I OD I 1 6105 3 2 5796 214 3 4 13 12 5 6 11 10 7 8 9 10 11 12 13 9 14 15 5785 5180 5160 4813 4755 4324 4096 3902 3840 2732 2250 2245 2086 8 16 11 04 17 250 2 18 Surface 7 6 5 4 3 2 1 Created by STG 3/24/04 3 536 3 330 3 3 38 40 50 60 14 Size Casing 13-3/8 Casing 9-5/8 Casing 7 Tubing Grade Thread L80 BTC L80 BTC L80 LT&C Depth 1700 4494 6200 Weight 68 ppf 47 ppf 29 ppf ID Description CICR @ 6105' 5796' - 6010 perf 5 spf alpha jet 5796 - 5810, 5822 - 5830, 5844 - 5868 5888 - 5900,5963 - 5994,6004 - 6010' CICR @ 5785' 5180' - 5716' perf 5 spf alpha jet 5180-5188,5198 - 5219, 5236 - 5248 5264 - 5329, 5360 - 5362, 5378 - 5388 5406-5408,5436-5468,5518-5527 5552 - 5578, 5606 - 5608, 5620 - 5630 5642 - 5650, 5668 - 5672, 5707 - 5716 CICR @ 5160' 4813' - 5146' perf 5 spf alpha jet 4813 - 4874,4928 - 4954,4970 - 4990 5024 - 5052,5060 - 5146 CICR @ 4755' Top of Liner @ 4324 CIBP @ 4096' 3902' - 3940' perf 5 sgL~lpha jet, 135/45 phasing 32 Gram .45" h~1 . 3~02 - 3908, 3913 - 3940 Packer with fla er ¥é31ve in place 2732' - 277Z g ,,_5 spf alpha jet, 135/45 phasing 32 Gram .45" holes. 2250' - 2300' perf 5 spf alpha jet, 135/45 phasing 32 Gram .45" holes. Weatherford csg patch from 2245' - 2305' 2086' - 2100' perf 5 spf alpha jet, 135/45 phasing 32 Gram .45" holes. Baker. lock set RBP, running tool on tubing above perforations for surface plug in 1992 Well cuttoff 5 feet below ground level. Modified by JRM 7/19/05 DATA SUBMITTAL COMPLIANCE REPORT 2/5/2002 Permit to Drill No. 1990680 Well Name/No. PIONEER UNIT BLT-01 Operator OCEAN ENERGY RESOURCES, INC APl No. 50-009-20006-90-00 MD 6200 TVD 6200 Completion Date 1/27/2000 Completion Status 1-GAS Current Status 1-GAS UIC N ..... ~Z~-~_~.U~____~Z~-~ --~-'~___~..~'£~_~ ............................... --~'-~-~' ~ ? -~.~' ? -- _ ~- ? '. ¥;' '. ~ _'~ -_' 7.~£L -~£~'_~.~---~L£ ~. .L~ ~- "~ ~.~ .... ~. -~'-i~L -~'-'-~-~ ~'~'~ ~ ~ ............. REQUIRED INFORMATION Mud Log No Samples N__9_o Directional Survey No -- DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Format Name (data taken from Logs Portion of Master Well Data Maint) Log Log Run Interval OH / Dataset Scale Media No Start Stop CH Received Number Comments Well Cores/Samples Information: Name Start Interval Dataset Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y / N Chips Received? Y / N Analysis Received? Y / N Daily History Received? .(~,~ N Formation Tops Receuived? {~)/N '~'"'~"~:"-' '*-,,,-~-.7...~ 5: * ": **' .... . ' . ' TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION COIE~IISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 May 3, 2000 Loretta Murphy Production Analyst Ocean Energy, Inc. · P.O. Box 549 Newcastle, Wy. 82701 Dear Ms. Murphy: We received your most recent submittal of information from the Pioneer Prospect coalbed methane wells in the Matanuska Valley, Alaska on April 26, 2000. This submittal does not bring Ocean Energy into compliance with the requirements of 20 AAC 25.071. A list of materials still outstanding follows: Pioneer Unit well 15DD, Permit Number 99-66, API Number 50-009-20017 1) Sepias of the open hole logs and the segmented bond tool (cement bond log). czdl/cnl/hdil, hdil/ac, sbt 2) Whole core description (lithology, porosity, fractures, cleats ect) 3) Whole core chips, as described in 20 AAC 25.071 (b) (4) 4) Whole core analysis, as described in 20 AAC 25.071 (b) (8) (C). In the context ofa coalbed reservoir these analysis include methane desorbtion measurements. Pioneer Unit well 15DA-WDW, Permit Number 99-64, APl Number 50-009-20015 1) Sepias and paper copies of all logs run in the well. (hdil/dal/gr/cal, ldl/cn/gr/cal, sbt) Pioneer Unit well 14CC, Permit Number 99-65, API Number 50-009-20016 I) Sepias and paper copies of all logs run in the well. (hdil/dal/gr/cal, zdl/cnl/gr/cal, sidewalls, sbt) 2) Digital sbt data 3) Whole core description (lithology, porosity, fractures, cleats etc) 4) Whole core chips, as described in 20 AAC 25.071 (b) (4) 5) Whole core analysis, as described in 20 AAC 25.071 (b) (8) (C). In the context of a coalbed reservoir these analysis include methane desorbtion measurements. 5) Sidewall core analysis and descriptions Loretta Murp'~:~:'"i:!i::~:,~ Production Analyst Ocean Energy, Inc. Pioneer Unit well BLT #1 RE, Permit Number 99-68, API Number 50-009-20006-90 1) Digital sbt data 2) Sbt sepia We note you have made a significant effort to cOmply with the reporting requirements of 20 AAC 25.071, however all of this information is long overdue and is considered very important to this developing play. If we have not been advised in writing by May 26, 2000 as to the disposition of these materials, I will recommend the Commission undertake an enforcement aCtion as described in 20 AAC 25.535. Notwithstanding, AOGCC recognizes the importance and potential benefit of OE's coalbed methane program to the State of Alaska. We look forward to your continued success as well as a good working relationship with the Commission. Please give me a call at (907)-793-1230 if you'd like to discuss this matter. Sincerely .... ./ Robert P. Crandall -' Senior Petroleum Geologist CCZ Robert Christenson Cammy Oechsli-Taylor Dan Seamount ... ,. April 6, 2000 Mr. I~,ubml P, Crandall Senior Petruleum Geologist 3001 Porcupine Drive Anchorage, Alaska 99501.3192 Dear Mr, CrandJ~ll: I am in receipt ofyour loiter daled April 4, 2000. I am curr, ndy working un your r~quesls. Thc one thing would lik~ to clarify is that OEI has not commenced i~icdion operations into well 15DA WDW, ~11 ol'tl~e wdl~ mmuioncd in you letter are currently shut in until sometime in the sprin~ when we will commence completitm opertitions, I have been in contact with Chuck Wilson our Drilling Supervisor to collect the additional dam Ihat you are requesting. A Itlrge portion of the data Illt~Sl collie I?om our geological depamment and will come om of /-hmslon. Chuck is CmTently in tim process orconmctlng thom to help us gather this inl~rmnlion. I have made it clear to Mr, Wilson that tl~c State of Alaska is growin~ impatJenl and tl~at we are overdue in our requirements. He will relay this to Houston and ask d~cm to forward lhe requested i~ems to the Newcastle offic~ so we cnn make eve~ eflbrt to see that )'ott receive all items that you have requested. I have in our files the daily drilling and opermions history, I will copy and forward these items immediately as u,'e[I as tile two lacking completion repons and the logs on the BLT ltl and 15DA WDW. I apologize tbr all of the confusion and thank you For you eoopemlion. Sincerely, ! Loretta Murphy Production Analyst La~ Curtis Newcasllc Area Foreman Ocean E,ergy~ Ine. #7 ('~'111[I'11[ l~h'ivu I'3). lh}x ~Y Nowc.~.,tle. Wyt~ming 82701 (7t)7) 74~-4052 Fax: (.lq7) 7464045 ALASKA OIL AND GAS CONSERVATION COPiMISSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 April 4. 2000 Ms. Loretta Murphy, Production Analyst Ocean EnerD' Resources. Inc. /37 Cantrel Drive Newcastle, Wyoming 82701 Re: Pioneer Unit, Alaska: Compliance with Alaska Oil and Gas Conservation Commission Reporting Regulations Dear Ms. Murphy: During 1999, Ocean Encrgy Resourccs. Inc. (OER) received permits to drill the 15DA WDW. 14CC? and 15DD wells within the Pioneer Unit near Wasilla, Alaska. OER also reccived a permit to re-drill and recompletc thc ARCO BLT #1 well within this same unit. It is the Alaska Oil and Gas Conscrvation Conmaission's (AOGCC's) understanding that operations were conductcd in each of thesc wells. Alaska Administrative Codes 20 AAC 25.070 and 20 AAC 25.071 require OER to submit reports, records, geologic data and well logs for each of these wells within 30 days after completion, abandonment, or suspension. Additionally? fluids injected into wells must be reported according to 20 AAC 25.420 and 20 AAC 25.432. We have rcceivcd rcports that OER has commenced injection operations into well 15DA WDW. According to our records. OER has not complied with these rcgulations, having only submitted incomplete information on two wells. Your cooperation is required to bring OER into compliance xvith Alaska regulations. Your response to this letter will dctcrmine the actions we will undertake in reaction to these regulator).' violations. Information lacking on cach of OER's Pioneer Unit wells includes, but is not limited to, the following: Pioneer 1. 2. 3. 4. 5. 6. 7. 8. 9. Unit 15DA WDW (Pemfit to Drill Number 99-064): Completion Report (Form 10-407) Geologic markers cncountered (name, measured depth and true vertical depth of each marker) Dailv drilling and operations history Sepia and reproduced copies of all logs run Digital data and verification listings for all logs run (on diskctte or tape) Data and rcports for production tests, drill stem tests or other formation tests (if conducted) Samples and laborator3_~ analytical results from conventional and sidewall cores (if obtained) Geochemical and formation fluid analyses (if obtained) Monthly Injection Report (Form 10-406) for thc months thc wcll was used for disposal purposcs. Ms. Loretta Murphy Ocean Energy Resources Inc. 2 April 4. 2000 Pioneer Unit 14CC (Permit to Drill Number 99-065): 1. Daily drilling and operations history 2. Sepia copies of all logs run 3. Digital data and verification listings for all logs run (on diskette or tape) 4. Data and reports for production tests, drill stem tests or other formation tests (if conducted) 5. Samples and laboratoD_? analytical results from conventional and sidewall cores (if obtained) 6. Geochemical and formation fluid analyses (if obtained) Pioneer 1. Unit 15DD (Permit to Drill Number 99-066): Geologic markers encountered (name, measured depth and true vertical dcpth of each marker) 2. Dailv drilling and operations history 3. Sepia copies of all logs run 4. Digital data and vcrification listings for all logs run (on diskette or tape) 5. Data and reports for production tests, drill stem tests or other formation tests (if conducted) 6. Samples and laboratory analytical results from conventional and sidewall cores (if obtained) 7. Geochemical and formation fluid analyses (if obtained) Pioneer 1. 2. Unit BLT # 1 (Permit to Drill Number 99-068): Completion Report (Form 10-407) Geologic markers encountered (name. measured depth and true vertical depth of each marker) 3. Daily drilling and opcrations history 4. Sepia and reproduccd copies of all logs run 5. Digital data and verification listings for all logs run (on diskette or tape) 6. Data and reports for production tests, drill stem tests or other formation tests (if 7 Geochemical and formation fluid analyses (if obtained) conducted) A cop3' of the AOGCC's rcgulations is attached for your review. A prompt reply to this notification is cxpcctcd. If you have any questions, please contact or Steve Davies or me at (907) 279-1433. Sincerely. Robert P. Crandall Senior Petroleum Geologist Attachment: Alaska Oil and Gas Conservation Commission Regulations. November 7. 1999 cc: Conunissioner Seamount ALASKA OI?'-\ND GAS CONSERVATION ''* )MMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL: GAS: XX SUSPENDED: ABANDONED: SERVICE: XX 2. Name of Operator Ocean Energy, Inc 3. Address P. O. Box 549, Newcastle, WY 82701 4. Location of well at surface 793' FNL & 1333' FWL Sec 793' FNL & 1333' FWL Sec 22-T17NR3W '. ~ ~ ;% ;~,* .,. - _ 793' FNL & 1333' FWL Sec 22-T17NR3W .... ; 5. Elevation in feet (indicate KB, DF, etc.) GL 100' 6. Lease Designation and Serial No. ADL 374124 Injection 7. Permit Number 99-68 8. APl Number 50- 009-20006-90 9. Unit or Lease Name ~11~., . : .. I '. Pioneer Unit ~ ~' ~ iL 10. Well Number , / BLT #1 RE APR 2. 200ri / 11. Field and Pool . Tyonek ~,,~,.~ 0JJ ~ GaS C0[ls. 12. Date Spudded 13. Date T.D. Reached I 14. Date Comp., Susp_. or Aband. I 15. Water Depth, if offshore I 16. No. of Completions 9/29/1999 I °-2/'22/2'8¢J~ ,/'-.~?_/'~¢,~,~1 feet MSL[ one 17. Total Depth (MD+'FVD) 18. Plug Back Depth (MD+TVD) 119. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 6200' TD 4092' PBTD I Yes: No: X I N/A feet MD I N/A I 22. Type Electric or Other Logs Run SEGMENTED BOND TOOL; PRODUCTION LOGGING SERVICES 23. CASING SIZE 13 3/8" CASING, LINER AND CEMENTING RECORD 9 5/8" WT. PER FT. 68 47 GRADE L-80 L-80 HOLE SIZE SE'FFING DEPTH MD TOP DO'I-YOM SURFACE 1700' SURFACE 4494' 4324' 6200' 17 1/2" 12 1/4" CEMENTING RECORD 1400 SX CLASS "G" 1117 SX CLASS "G" 29 L-80 8 3/4" 470 SX CLASS "G" AMOUNT PULLED 24. Perforations open to Production (MD+'I-VD of Top and Bottom interval, size and number) PRODUCTION PERFS 2086' - 2100' 5 SPF 2732'- 2772' 5 SPF INJECTION PERFS 3902'- 3908' 5 SPF 3913' - 3940' 5 SPF .45"HOLE .45"HOLE .45"HOLE .45"HOLE tnd 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (ME)) 2 7/8" 1073' 3840' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) 2086'-2100' 2732'-2772' 3902'-3908' 3913'-3940' IAMOUNT & KIND OF MATERIAL USED 60 BBLS 2% KCL WTR 50 BBLS 2%KCL .5% SURF.+1%EDTA 30 BBLS 2% KCL WTR 30 BBLS 2% KCL WTR PRODUCTION TEST Date First Production 1/26/00 Method of Operation (Flowing, gas lift, etc.) swabbed; current y shut in Date of Test i/26/00 PRODUCTION FOR TEST PERIOD => rHours Tested 5 1/2 Casing Pressure SI 400 OIL-BBL 0 GAS-MCF light gas cut Flow Tubing CALCULATED OIL-BBL GAS-MCF Press. 24-HOUR RATE => 0 0 28. CORE DATA UKiblNAL 163 WATER-BBL I OIL GRAVITY-APl (corr) 792 In/a Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. 3omments: njectivity test and leak off survey performed on injection perfs; 30 bbls 2% KCL water 1/2 BPM 600 PSI 1 BPM 1000 PSI; 1 1/2 BPM 1450 PSI; 2 BPM _~000PSI. ISIP1500 PSI. ~erforations at 2250' - 2300' 5SPF .45" hole are isolated behind a HOMCO casing patch from 2245' -2305'. Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. ,----..,, 30. GEOLOGIC MARKERS }RMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Glacial Deposits Surf. Tyonek 525' .. 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Form 10-407 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion repod and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other space on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the productin intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". PIONEER UNIT FLUID SAMPLE ANALYSIS 11/2/99 COMPONENT UNIT BASE #1 #2 #3 ~f14~ #5 CHLORIDE mg/I 9920 8690 5960 7850 4990' SULFATE mg/I 25 37.2 27.8 26.3 2.35 MAGNESIUM mg/I 6.86 32.5 34.7 0.116 18 CALCIUM mg/I 65.8 578 629 8.6 100 SODIUM mg/I 1250 4080 3860, 330 2830 !BARIUM mg/I 8.99 19.1 18.6' 0.0302 7.36 'IRON mg/I 0.373 53.7 118 0.162 0.05 'POTASSIUM mg/I 9830 930 805 6760 109 PH ph units 7.8 7.94 8.06 9.63 7.56 HARD N ESSasCaCO3 mg/I 1 {92 1580 1710 22 324 Sp. Gr. ~SpG@25c 1.0181 1.013 1.015 1.016 1.009 SAMPLE DESCRIPTION BASE FLUID 10/07/99 CITY WATER W/2%KCL + .5% DOWELL F40 NONIONIC SURFACTANT + 1% DOWELL U42 EDTA. SAMPLE TAKEN @ DISPLACEMENT TANK WHILE PUMPING BREAKDOWN. #1 10/07/99 1702-15DD SWAB SAMPLE ZONES 4052-62' 4010-14' DARK RED WATER W/3% BS. ANALYSIS DONE W/FILTERED SAMPLE. #2 10/11/99 1702-15DD SWAB SAMPLE ZONES3748-56' 3884-90' 3916-22' DARK RED WATER 2% BS #3 10/13/99 10/18~99 11/02/99 1702-15DA SWAB SAMPLE ZONES 3700-50' 3964-84' 3988-98' 4060-80' DARK RED WATER 2-3% BS ANALYSIS RESULTS QUESTIONABLE BLT #1 SWAB SAMPLE ZONE 1 3902 - 3940' CLEAR SLIGHTLY SALINE WATER BLT #1 SWAB SAMPLE ZONE 3 2250 - 2300' CLEAR SLIGHTLY SALINE WATER Operations Activity Summary Well ID: Arco BLT #1 Well Name: Arco BLT #1 Rpt. Ops Non- No. Date/Time From To Hfs Code Product Activity Description Ocean Energy Page 1 1 26-Sep-99 8:00 0:00 16 R/D 2 27-Sep-99 0:00 0:00 24 DMOB 3 28-Sep-99 0:00 0:00 24 R/U 29-Sep-99 0:00 7:00 7 R/U 29-Sep-99 7:00 18:00 11 R/U 29-Sep-99 18:00 23:30 5.5 NU/ND 29-Sep-99 23:30 0:00 0.5 OTHER 5 30-Sep-99 0:00 5:00 5 OTHER 30oSep-99 5:00 15:00 10 NU/ND 30-Sep-99 15:00 19:00 4 BOPOT 30-Sep-99 19:00 20:00 1 NU/ND 30-Sep-99 20:00 0:00 4 CMTD 6 01-Oct-99 0:00 5:00 5 CMTD 01-Oct-99 5:00 6:00 1 CRCF 01-Oct-99 6:00 8:00 2 PRTS 01-Oct-99 8:00 9:00 1 OTHER 01-Oct-99 9:00 10:00 1 MONFC 01-Oct-99 10:00 10:15 0.25 OTHER 01-Oct-99 10:15 10:30 0.25 CFCO 01-Octo99 10:30 15:30 5 CLN 01-Oct-99 15:30 22:00 6.5 TIH 01-Oct-99 22:00 22:30 0.5 SERV 01-Oct-99 22:30 0:00 1.5 TIH 7 02-Octo99 0:00 3:00 3 TIH 02-Oct-99 3:00 4:30 1,5 CRCF 02-Oct-99 4:30 6:00 1,5 PRTS 02-Oct-99 6:00 10:00 4 OTHER 02-Oct-99 10:00 13:00 3 OTHER 02-Oct-99 13:00 14:00 1 CRCF 02-Oct-99 14:00 20:30 6.5 PU/LD 02-Octo99 20:30 0:00 3.5 NU/ND 8 03-Oct-99 0:00 6:00 6 NU/ND 03-Oct-99 6:00 0:00 18 FUD rd prepare to move, move mud tanks off loc to clean up liner general rig down, clean up loc. Pu liner, prepare for rig move. Rig crew worked 8 hrs today install cellar & level loc, start to move rig at 1000 hrs, lay liner, mud boat, & set sub base and spot rig. Shut down for night. Rig is all on loc except for pipe baskets and one mud pump and trailers. Crew worked 10 hrs. wait on daylight miru. Mix spud mud to drl rathole install 11 x 13 5/8 csg slips, had to run dc into 9 5/8 csg and tie rig up truck winch line around collar and pull 9 5/8 csg over to set slips., install 11 3m x 13 5/8 3 m tbg spool and test same. drl rat hole drlg rat hole w/mud motor nu bope test bope, 300 Iow, 3000 high, install wear bushing drlg cmt 25 - 100, using mud mtr drlg cmt w/mtr 100 - 298, good firm cmt to 205 then weak spot 205- 225, then firm to 250 then fell thru to 284 to top of retainer cir hole clean while ru BJ for pressure test. pressure test 9 5/8 csg, test to 250 psi held steady for 10 rain, bring to 500 and bled to 400 in 10 min, bring to 770 bled to 550 in 10 min, bleed off 1/4 bbl back, less than .1 bbl lost while testing, bring up to 777 bled to 560 in 10 min. Bring to 1000 bled to 872 in 30 min. Bleed off, 1/4 bbl back, <.25 bbl lost during test. blow down well with air, no apparent influx of gas or fluid monitor well for influx of gas or fluid, no gas to surface blow down well, no fluid influx or gas to surface fill hole with fresh water drl cmt retainer at 284 w/mtr. tih to 1724 tag up and drl on retainer, tih lube & service rig rih tih tag up at 4081 cir test csg to 1000 psi for 30 min. 1.25 bbls pumped, all but .3 back clean mud tanks so can dispalce hole to 2% KCL haul and mix 350 bbls 2% KCL fluid (affluient water from dewatering) displace 11.2 mud in hole to 2% kcl water Id dp & dc &mtr nd bope, install 11" 3m blind flange, clean mud tanks nd, install 11" 3M 'blind flange on well head, clean mud tanks, rig released at 0600 hrs 10-3-99 rd prepare rig to stack out in D&J Development yard Printed: 14:15 07-Apr-O0 End of Report ~ "'~COMPLETION SUMMARY p ~o~ .~ ~ onn~ ARCO BLT t41 10/15/99 MIRU CH&P ~G 19. ~ ~ TEST BOPE A~ M~OLD. 1 O/16/99 PU 8 ½"BIT AND CASING SCRAPER. TIH W/131 JTS 2 7/8" 6.5# J55 EUE TBG TO PBTD AT 4092'. SWAB FL TO 2600' 10/17/99 POOH W/TBG. RU ATLAS WIRELINE. PERFORATE W/4 ½" HSC 5 JSPF 43 GRAM CHARGES .45" PERFS 3913-40' & 3902-08' 165 SHOTS. PU BAKER RETRIEVAMATIC PACKER AND TIH W/30 JTS TBG. 10/18/99 SICP 100 PSI FINISH TIH. SET PACKER ~ 3836'. WELL BEGAN FLOWING UP TBG. FLOW RATE 4 BPH. RU SWAB SWAB RATE 25 BPH. RECOVERED 87 BBL TOTAL. 10/19/99 SITP 380 PSI FLAMMABLE GAS TO SURFACE. RU SWAB IFL 100'. SWAB FOR 6 HRS. RECOVERED 126 BBL FLUD. FFL 2700' FINAL RATE 20 BPH. 10/20/99 SITP 450 PSI FLAMMABLE GAS TO SURFACE. RU SWAB FL AT SURFACE. MADE 1 RUN. RU ATLAS WIRELINE AND RIN W TANDEM PRESSURE RECORDERS TO 3915'. RU BJ SERVICES AND PUMP INJECTIVITY TEST AND LEAK OFF SURVEY W 30 BBL 2% KCL WATER. ½ BPM 600 PSI 1 BPM 1000 PSI 1 ½ BPM 1450 PSI 2 BPM 2000 PSI. ISIP 1500 PSI. SI AND RECORD PRESSURES FOR 48 HRS. 10/22/99 RETRIEVE PRESSURE RECORDERS AND FORWARD DATA TO DENVER OFFICE. 10/23/99 SITP 300 PSI. RELEASE PACKER AND POOH. LD TOOLS. TIH W/ 25 JTS TBG. 10/25/99 POOH W/TBG. RU ATLAS WIRELINE. WL SET BAKER MODEL D PERMANENT PACKER W/FLAPPER ASSEMBLY AT 3840'. 10/26/99 PU BAKER F LATCH PLUG ASSEMBLY AND RIH W/TBG. LATCH INTO MODEL D PACKER AT 3840'. RELEASE FROM LATCH ASSEMBLY AND LD 1 JT TBG. SWAB FL TO 2000'. POOH W/TBG. 10/27/99 RU ATLAS WIRELINE. PERFORATE W/4 ½" HSC 5 JSPF 43 GRAM CHARGES .45" PERFS 3732-72' 200 SHOTS. RIH W/BAKER 10/28/99 10/29/99 10/30/99 10/31/99 11/01/99 11/02/99 11/03/99 11/04/99 11/05/99 RETRIEVAMATIC PACKER AND SET ~ 2684'. SWAB TO XN NIPPLE AT 2684'. RECOVERED 4 BBL W/NO FLUD ENTRY. SITP 20 PSI. FLAMMABLE GAS TO SURFACE. RU SWAB. NO FLUD ENTRY. RU RIG PUMP AND FILL TBG W/15 BBL 2% KCL WATER. ESTABLISH INJECTION AT 1/8 BPM 2350 PSI. SWAB ~.~ ~, BACK 15 BBL FLUID. '~'<,~2 SITP 0 PSI NO ENTRY. RU BJ SERVICES TO BD PERFS 3732-72' W/50 BBL 2% KCL WATER +.5% SURFACTANT + 1% EDTA AND 175 BALL SEALERS. FLUSH W/30 BBL 2% KCL WATER. FINAL RATE 4.5 BPM 3370 PSI. SWAB BACK BD FLUID. RECOVERED 18 BBL OF 80 BBL LOAD. SITP 0 PSI RU SWAB [FL 880'. SWAB TO XN NIPPLE AND MADE 1 RUN/HR FOR 6 HRS. RECOVERED 19 BBL FLUID FINAL FL2450' 1/3 BPH. 37 BBL OF 80 BBL LOAD RECOVERED. SITP 0 PSI. [FL 1900'. SWAB 3 HRS RECOVERED 4 BBL FLUID. 41 BBL OF 80 BBL LOAD RECOVERED. RELEASE PACKER AND SWAB FL TO 1200'. POOH W/TBG. SICP 0 PSI. RU ATLAS WIRELINR. PERFORATE W/4 ½" HSC 5 JSPF 43 GRAiM .45" SHOTS. 2250-2300' 250 SHOTS. PRESSURED TO 75 PSI IN 2 HRS WHILE PERFORATING. BD PRESSURE. FLUID TO SLrRFACE IN 10 MINUTES. PU BAKER MODEL G RBP AND RETRIEVAiMATIC PACKER. TIH W/TBG. SET RBP AT 2510' PKR AT 2188'. FLOWED 96 BBL WHILE TRIPPING. SWAB 1 HR RECOVERED 20 BBL SLIGHTLY GAS CUT FLUID. SITP 380 PSI. GAS TO SURFACE. BD AND FLOWED 36 BBL IN 30 MINUTES. SWAB 8 HRS. FFL 745' FINAL RATE 32 BPH. 354 BBL RECOVERED FOR DAY. LIGHTLY GAS CUT WATER W/3% SOLIDS. SITP 380 PSI. BD AND FLOWED 26 BBL IN 30 MIN. SWAB 3 HRS. RECOVERED 108 BBL. RU RIG PUMP. PUMP 225 BBL INJECTIVITY TEST AT ½ TO ¼ BPM 750 - 900 PSI. SITP 380 PSI. PUMPED 500 BBL INJECTIVITY TEST AT 1 BPM FROM 1450 TO 1900 PSI. ISIP 1450 PSI 15 MIN 1075 PSI. SITP 380 PSI. BD TBG AND RELEASED PKR. RETRIEVE RBP AND RESET RBP AT 2196'. TEST PLUG TO 500 PSI. RU ATLAS WIRELINR PERPORATE W/4 ½" HSC 5 JSPF 43 GRAM .45" PERFS. 70 TOTAL SHOTS. 380 PSI ON WELLHEAD IN 5 MINUTES W/ ~,Jk~,~ ~ FLUD TO SURFACE. * 11/06/99 SICP 380 PSI. RU ATLAS WIRELENqE RAN 8.5 GUAGE RING AND TAG RBP AT 2196'. RUN BAKER SC1 PACKER W/XXN TBG PLUG IN PLACE. SET PACKER AT 2035'. BD CASING AND MONITOR PRESSURES. 11/07/99 SICP 0 PSI. PU BAKER SC1 SEAL ASSEMBLY AND RIH. LAND IN SC1 PACKER AT 2035'. RETRIEVE XXN PLUG FROM XN NIPPLE. 380 PSI ON TBG. BD FLOWING 1" STREAM. SWAB TO X NIPPLE IN 3 HRS FFL 1550'. FINAL RATE 18 BPH WATER. RECOVERED 51 BBL. 11/08/99 SITP 380 PSI. FLUID TO SURFACE. NO GAS. SWAB TO X NIPPLE AT 2035' AND SWAB FOR 7 HRS. FFL 1000' FINAL RATE 26 BPH CLEAN WATER NO GAS. 225 BBL RECOVERED FOR DAY. 11/09/99 SITP 380 PSI GAS TO SURF. BD WATER TO SURF. SWAB 5 HRS AT 26 BPH FL 1000'. ENTRY DECREASED TO 13 BPH 1500' FOR 2 HRS. 203 BBL LIGHTLY GAS CUT FLUID RECOVERED. 11/10/99 SITP 380 PSI. GAS TO SURF. BD WATER TO SURF. SWAB 6 HRS AT 20 BPH FL 1000'. 144 BBL MODERATELY GAS CUTFLUID RECOVERED.. 11/11/99 SITP 380 PSI. GAS TO SURF. BD WATER TO SURF. SET XXP PLUG IN XN NIPPLE AT 2044'. STING OUT OF SC 1 PACKER AND LD 4 JTS TBG..,ND BOPE. NU WELLHEAD. LAND TBG AT 1920'. RDMO CH&P RIG 19. SI WAIT ON COMPLETION TOOLS. 12/14/99 MIRU CH&P RIG 19. NU BOPE AND MANIFOLD. TEST SURFACE EQUTPMENT TO 2000 PSI. PU 4 JTS TBG AND STING INTO SC1 PACKER AT 2035'. UNABLE TO RETRIEVE XXP PLUG FROM XN NIPPLE AT 2044'. STING OUT AND POOH W/TBG. LD SEAL ASSEMBLY. 12/15/99' PU RETRIEVING HEAD AND TIH W/TBG. RETRIEVE SC 1 PACKER AND POOH. RIH W/RETRIEVING HEAD AND 65 JTS TBG. 12/16/99 SICP 380 PSI. TIH AND ENGAGE RBP AT 2196'. STRONG FLOW WHEN RBP WAS RELEASED. POOH W/TBG. RBP WAS NOT RECOVERED. TIH AND ENGAGE RBP AT 2196' FOLLOW RBP DOWNHOLE TO 2504' AND RESET. RELEASE RBP AND POOH. LD TOOLS. 12/17/99 12/18/99 12/19/99 12/20/99 01/04/00 01/05/00 01/06/00 01/07/00 01/08/00 01/09/00 01/16/00 01/17/00 01/18/00 SICP 380 PSI. PU F LATCH RETRIEVING HEAD AND TIH TO 3500'. SD FOR RIG REPAIR. REPAIR RIG. TAG FILL AT 3828'. WASH DOWN TO PACKER AT 3840'. RETRIEVE F LATCH ASSEMBLY AND POOH. LD TOOLS. SICP 380 PSI. PU 8 ½" BIT, CASING BRUSH, CASING SCRAPER AND 8.525 STRING MILL. T1H TO 2350'. WORK TOOLS THRU PERFS AT 2100 AND 2300'. TIGHT CASING FROM 2090' TO 2100'. POOH AND LD TOOLS. SICP 380 PSI. PU BAKER RBP AND RIH W/34 JTS TBG. SET RBP AT 1074'. LD 4 JTS TBG. SWI FOR HOLIDAY. 24 HOUR SECURITY ON LOCATION. RETRIEVE RBP AT 1074'. POOH AND LD TOOLS. PU WEATHERFORD 8.30" ID CASING PATCH AND RIH. SEAT PATCH AT 2245' TO 2305'. POOH W 15 JTS TBG. POOH AND LD WEATHERFORD TOOLS. PU BAKER MODEL G RBP AND RETRIEVAMATIC PACKER. TIH AND SET PLUG AT 2153'. SET PACKER AT 2037' SITP 0 PSI. RUN TANDEM PRESSURE RECORDERS AND SET IN XN NIPPLE AT 2037'. RU BJ SERVICES. INJECT 2 BBL FLUID AT 1200 PSI. SI AND RECORD PRESSURES. RETRIEVE RECORDERS. DOWN LOAD DATA AND FORWARD TO DENVER OFFICE. SWAB TO XN NIPPLE AT 2037' RECOVERED 15 BBL WATER. NO FLUID ENTRY. SITP 20 PSI. GAS TO SURFACE. SWAB. IFL 1850' 200' ENTRY. SWAB 6 HRS W/NO ADDITIONAL ENTRY. SD WAIT FOR PERFORATING TRUCK FROM NORTH SLOPE. RELEASE PACKER SWAB FL TO 700' AND POOH W/TBG. RU ATLAS WIRELINE. TAG RBP AT 2153 '. REPERFORATE W/4 ½" HSC 5 JSPF 43 GRAM .45" 2086-2100' 70 SHOTS. TIH W RETRIEVAMATIC PACKER AND SET AT 2046', SITP 0 PSI. SWAB [FL 700'. SWAB TO XN AT 2037' W/NO ENTRY. SITP 20 PSI GAS TO SURF. SWAB IFL 1700' 300' ENTRY. RU BJ SERVICES. PUMP 31 BBL 2% KCL WATER. 4 BPM 2330 PSI. ISIP 1810 PSI. 15 MIN 1290 PSI. SWAB BACK 16 BBL OF 31 BBL LOAD. NO ENTRY. 01/19/00 SITP 20 PSI GAS TO SURFACE. FIL 1800' 200' ENTRY. SWAB 6 HRS W/NO ENTRY. 01/20/00 SITP 20 PSI IFL 1700' 300' ENTRY. SET 1 PRESSURE RECORDER IN XN NIPPLE AT 2034'. BJ INJECTED 30 BBL 2% KCL WATER AT ¼ BPM 1670 TO 1830 PSI. ISIP 1675 PSI. RECORD LEAK OFF FOR 24 HRS. 01/21/00 RETRIEVE RECORDER AND FORWARD DATA TO DENVER OFFICE. SWAB TO XN NIPPLE. RECOVERED 12 BBL NO ENTRY. 01/22/00 SITP 0 PSI. RELEASE PACKER AND RETRIEVE RBP AT 2150'. PULLED TIGHT W/RBP IN PERFS 086-2100'. RELEASE TBG FROM RBP AND POOH. LD PACKER. 01/23/00 RIH W/RETRIEVhNG HEAD AND BUMPER SUB. UNABLE TO WORK PLUG FREE. RELEASE AND POOH W/TBG. 01/24/00 PU RETRIEVING HEAD, BUMPER SUB AND 4 6" DC'S. RIH AND ENGAGE RBP. WORK PLUG FREE AND RESET AT 2160'. POOH AND PU 8.525 STRINGMILL. RIH AND WORK MILL THRU TIGHT CASING 2086-2100'. RETRIEVE RBP AND WORK PLUG UP THRU TIGHT CASING. POOH W/10 JTS . 01/25/00 SICP 200 PSI. POOH AND LD TOOLS. PU RETRIEVAMATIC PACKER AND RIH. SET PKR AT 2160'. SWAB TEST PATCH 2245-2305'. IFLSURFACE W/LIGHT FLOW. SWAB 2 ½ HRS. FFL 600' 35 BPH 3% SOLIDS LIGHTLY GAS CUT FLUID. 01/26/00 SITP 380 PSI. BD TBG FLOWED 65 BBL IN 1 HR. RELEASE PACKER AND SWAB. FFL 400' 40 BPH LIGHTLY GAS CUT FLUID W/SOLIDS. POOH LD TOOLS. 01/27/00 SICP 380 PSI. PU BAKER MODEL G RBP AND RIH W/35 JTS TBG. SET RBP AT 1104'. LD 4 JTS TBG. SWAB FL TO 200'. WINTERIZE WELLHEAD. ND BOPE. NU WELLHEAD. 01/28/00 RDMO CH&P RIG 19 01/29/00 SECURE WELLHEAD W/CHAINS AND LOCKS. INSTALL WELLHEAD SHELTER. SI WAIT ON FRAC EQUIPMENT. OCEAN ENERGY RESOURCES, INC. DAILY RIG REPORT Well: PIONEER UNIT ARCO BLT#1 Perfs: Location: SEC 22 T17N R3W TD/PBTD: Date: 9/16/99 KB/G L Work Done on: 9/15/99 Others: Present Operation: PRESSURE TESTING BOP N/A SURFACE 100/130' Operations Planned: DRILL OUT SURFACE PLUG Time From To DAILY OPERATIONS 9/13 - 9/14 MIRU CH&P DRILLING RIG 19 W/RELATED EQUIPMENT. INSTALL 13 3/8" RISER AND CASING HEAD OBSERVED MINOR GAS SURFACING BETWEEN 9 5/8 AND 13 3/8 CASING. 9/15 7:00 PU 1 JT 9 5/8" BUTTRESS THREAD CASING AND TIE BACK TO 9 5/8' CASING AT 36' KB.PU 80M# AND SET CASING SLIPS. 13 3/8 CASING MOVED UPHOLE 1 1/2 TO 2" WHILE PULLING ON 9 5/8 CASING. RETURNED TO POSITION WHEN TENSION RELEASED. 14:00 ~MADE FINAL CASING CUT AND INSTALLED 11" 3M TUBING SPOOL. 14:00 NU BOPE AND MANIFOLD.(LOST 6 HRS RIG TIME INSTALLING STUDS TO 22:00 BOTTOM OF BOP. HOLES WERE EXTREMELY RUSTED AND CORRODED.) 22:00, 0:00 BEGIN TESTING BOPE. BLIND RAMS WOULD NOT HOLD FLUID AT 0 PSI. COSTS PREVIOUS DALLY CUMULATIVE Rig $8,760 $8,760 Supervision $2,250 $2,250 Rentals $400 $400 Roustabouts $650 $650 Transportation $3,800 $3,800 Cement, Acid, Frac. $0 $0 Perforating, Logging $0 $0 Subsurface Pum. ps $0 Rods, Scrapers $0 :l-ubin9, Subs, SN $0 TAC, Packer, Repair . $0 Others WELLHEAD $16,500 $16,500 Location $750 $750 Misc. $0 Electrical $0~ Water $850 $850 Contingenc¥ $3,396 $3,396 TOTAL $37,356 $37,356' OCEAN ENERGY Well: Location' DALLY RIG REPORT Date: Work Done on: Present Operation: PIONEER UNIT ARCO BLT#1 Perfs: N/A SEC 22 T17N R3W TD/PBTD: 4092 10/16/99 KB/GL 100/130' 10/15/99 Others: PU TBG AND SCRAPER Operations Planned: PREP TO PERFORATE Time From To DAILY OPERATIONS 10/14~99 MIRU CH&P RIG 19 10/15~99 NU AND TEST BOPE AND MANIFOLD COSTS PREVIOUS DALLY CUMULATIVE Rig $88,135 $8,625 $96,760 Supervision $9,700 $1,500 $11,200, Rentals $16,550 $1,200 $17,750: Roustabouts $3,650 $450 $4,100 Transportation $106,750 $3,350 $110,100 Cement, Acid, Frac. $0. $0 Perforating, Logging $8,000 $0 $8,000 Subsurface Pumps $0 Rods, Scrapers $0 Tubing, Subs, SN $24,600 $24,600 TAC, Packer, Repair $0 Others $16,500 $0 $16,500 Location $750 $0 $750 Misc. $13,075 $0 $13,075 Electrical/Fuel $5,900 $0 $5,900 Water $1,450 $900 $2,350 Contingency $27,046 $4,063 $31,109 TOTAL $297,506 $44,688 $342,194 OCEAN ENER.., ' ; PIONEEP-, UNIT AP, CE) ELTO1 Perf$~ TD/PBTD: KB/GL L=ca~=n: , SEC 22 T17N R3W Data: : 9/I 6/9-~ 'vV~rK DDne on; -9716/99 Prasant Operation: PRES$~Iq.E TESTING EtOF Operaticms Planned: DRILL OUT .SURFACE PLUG DAILY RIG REPORT N/A SURFACE L 100/130' ,,, ..Tim? i F.~m T_o_. I ~ DAILY OPL=RATION$ MIRU CH~F DRILLING Rl~,19 W/RE~TED EQUIPMENT. IINST~LL !~3 3/8' R':SER &ND CASING ! 7:0o f r l- ~4:00 '9/15 , ~U I JT 9 5/8' SUTTRESS THRF_.,~D'~ASING AND i"t~-~ACK TO 9 518' CASING ........ jAT 36' KB.PU 80MC.AND SET CASING SLIPS --'14:1~0! MADE FINAL C,~SiNe CUT AND-IR~'TAE'LED 1 I" 3M TOBING SPI~OL. NLI SOPE AND MANIFOLD_(LOST 6 HRS RIG TIME INSTALLING STUDS TO !_ ..2,2.:g0 B(;;iTTOT~I ~F BOP. HOLES WERE EXTREMELY RUSTED AND CORRODED.) ,.. 0:0O BEGIN TESTING 8OPE. BLINQ RAMS WCULD NOT HOLD FLUID AT O PSI. ,I CC, Sf$ PREVIOUS DAILY CUMULATIVE '~F.a~Tiai°n ..... , ..........I , ~e;%a s i ~400i , ~400 ~T,~nspo~fion ~ ' ......... $3,800 $3,8~ Cement. A~id, Fmc. ~ "' " Subsu~ Pump~ ¢~o~s. 8cm~ ~ ....... , .~, ......... SN .............. '", TAG, Packer, Re~.(L ._. I ~0 ;O~e~ WELLHEAD .... ..... Lo~tion ' I $750 $750 M~sc. ' $0 v~te; .......... ... $~0~ .. $880 Con~i.~gency . ~- .... =..- .......... TOTAL, ~' " S37,~j ". ~37,356i OCEAN ENERGY RESOURCES, INC. Well: PIONEER UNIT ARCO BLT#1 Location: SEC 22 T17N R3W Date: 10/17/99 Work Done on' 10/16/99 Present Operation: POOH TO PERFORATE Perfs: TD/PBTD: KB/GL Others: DAILY RIG REPORT N/A 4092 100/130' Operations Planned: TEST LOWER PERFS Time From To DAILY OPERATIONS 10/16/99 PU 8 1/2' BIT, CASING SCRAPER AND 131 JTS 2 7/8" 6.5# 8RD EUE J-55 TBG TAG PBTD AT 4092'. RU TO SWAB. SWAB FL TO +/- 2600'. SWIFN COSTS PREVIOUS DAILY CUMULATIVE !Rig $96,760 $4,875 $101,635' Supervision $11,200 $750 $11,950 Rentals $17,750 $600 $18,350 Roustabouts $4,100 $0 $4,100 Transportation $110,100, $0 $110,100 Cement. Acid, Frac. $0 $0 Perforating, Loggin~l $8,000' $0 $8,000 Subsurface Pumps $0 Rods, Scrapers $0 Tubing, Subs, SN $24,600 $0 $24,600 TAC, Packer, Repair $0 Others $16,500 $0 $16,500 Location $750 $0 $750 Misc. $13,075 $0 $13,075 Electrical/Fuel $5,900 $0 $5,900 Water $2,350 $450 $2,800 Contingency $31,109 $668 $31,776 TOTAL $342,194 $7,343 $349,536 OCEAN ENERGY DAILY RIG REPORT Well: PIONEER UNIT ARCO BLT#1 Perfs: Location: SEC 22 T17N R3W TD/PBTD: Date: 9/17/99 KB/GL Work Done on: 9/16/99 Others: Present Operation: SI RIGGED DOWN AND MOVED OFF N/A SURFACE 100/130' Operations Planned' MONITOR SURFACE PRESSURES AND CONSIDER OPTIONS Time From To DAILY OPERATIONS 9/16/99 0:00 5:00 !ATTEMPT TO TEST PIPE RAMS AND MANIFOLD. PRESSURE TO 1200 PSI LEAKED TO 0 PSI IN 2 MINUTES. CONTINUE TRYING TO TEST AND LOCATE LEAK. EVENTUALLY ESTALISHED INJECTION ON 9 5/8 CASING AT 1/8 BPM 700 PSI BROKE CIRCULATION TO SURFACE ON 9 5/8 X 13 3/8 ANNULUS WITH 1/2 BBL PUMPED. '1 PROBABLE LEAK AT 1ST 9 5/8 CASING COLLAR. 5:00 10:00 SD WAIT ON ORDERS 10:00 17:00 RDMO CliP DRILLING RIG 19 , , COSTS PREVIOUS DAILY CUMULATIVE Rig $8,760 $.6,375 $15,135 Supervision $2,250 $750 $3,000 Rentals $400 $400 $800 Roustabouts $650 $400 $1,050 Tran s p ortation $3,800 $2,200 $6,000 Cement, Acid, Frac. $0 $0 Perforating, Logging $0 $0 Subsurface Pumps $0 Rods, 'Scrapers $0 Tubing, Subs, SN $0 TAC, Packer, Repair $0 Others WELLHEAD $16,500 $0 $16,500 Location $750 $0 $750 Misc. $0 Electrical '$0 Water $85O $0' $85O Contingency $3,396 $1,013 $4,409 TOTAL $37,356 $11,138 $48,494 . CC EAN EN E RGY DAILY RIG REPORT Well: PIONEER UNIT ARCO BLT#I Perfs: N/A L~cation:_.. SEC 2~'TI'~N R3W TD/PBTD: SURFACE Date: 9117t99 -- KB/G L 10DI130' Work Done on: _ @/!6199 Other~: Present OperatJcn: 8l RIGGED DOWN AN0' M.OVED OFF " Opera,.ions Planned: ,MONIToR 8U'RFACE PRESS. URES AND'~ON$1DER OPTI'ONS ". .... Time 0:00! . DAILY OPERATIONS, TEST PIPE RAMS AND,MANIF,.OLD. PR,ESSL~F;;~..F, TO'1209 P~ 'LEAKED TO E TRYING TO LEAK. INJECTION ON 9.5/8 CASING A'¢'~,/8 BPM 700 PSI BROKE CIRCULATION TO 8UR! N 9 5/8 X 13 3t8 ANNU .E 9 518 CASING COLLAR. ON ORDERS NG RIG 19 PUMPED. · ,J i COSTS PREVIOUS DAILY CUMULATIVE $8,7601 86 $15 OCEAN ENERGY DALLY RIG REPORT We!t: L~ca[ion; Da[e; Work [;one Presem Opsration: Oloerations Planned; PIONEER. UNIT ARCO BLT#1 SEC 22 TI 7N R3W 9/22/99 9-/2t/99 MONITOR SURFACE PRE',.qSURE8 Perf$: N/A TDIPBTD: 81~RFACE KB/GL 10011 Others: 'Frcm To . ! . DA. ILY OPERATIONS ' ~9 ~8 X 13 3/8 hNNULUS 25 PSI. ' ' COSTS PREVIOUS DAILY CUMULATIVE LRig ........ $i5,135 $0 " $15_L188' J Sup_ep. dslon ~3,o0o So $_2, o~0o jRe~-tals .... $8~0 S0 $800 ,Roust~b6uts ' "~1~050 " $0 " ~rans~o~tion .... $6,000 $0 I~ment. A~id, Fmc.' " .... J~edorating, LO~in~ ~ ' 80 '" ~0 LCubsu~'Pumps ' ' ' !Tubing, Subs, SN $0 ,..~ Packer, Repair , $0 ~ers . . , WELLH~D ~te,SO0 80 $1e~500 LccatiCn- ' $750 ¢0i ,~. ' ....... ~Elec[rical ..... iWater ' " ~50 '-$0 ~850 'Contingen'c~ ' .. '" $4,4q9' ' .. $0 ' $4,40BJ ~ .... 'TOTAL _. ~8,494 $0 Well Summary Report Well ID: Arco BLT #1 Ocean Energy Well Name: Arco BLT #1 Operator: AFE Nos: Spud Date: Section: Location: Ocean Energy, Inc. DMW927C 22 Township: 793' FNL & 1333' FWL Reports for 06:00 on date shown 26-Sep-99 Field: Pioneer Unit 17N Range: 3W Current Depth: Present Ops: rd, wait on loc, Operations Summary: rd prepare to Comments: Mud Data: Surveys: None Days S.S.: Hole Drilled: Ave ROP: move, move mud tanks off loc to clean up liner (16 hrs) got welhead off of BLT and welded up 9 5/8 stub into the collar, will weld on cap and then test to 1000 psi and if all OK will then proceed to reinstall 13 3/8 pipe and well head. When pulled slips broke a retaining ring. Have to get pads, will put in slips, tbg spool when get rig to loc. None Daily Costs: $102,000 Well Costs: $102,000 27-Sep-99 Current Depth: Hole Drilled: Ave ROP: Operations Summary: general rig down, clean up loc. Pu liner, prepare for rig move. Rig crew worked 8 hrs today (24 hfs) Comments: the tested 9 5/8 csg, to 1000 psi drop to 200 psi in 10 min., No visible leaks from csg collar where it was welded solid. Could not dectect any water infux in the 13 3/8 x 9 5/8 annulus. Pumped max 3 gals fluid, the 13 3/8 x 9 5/8 annulas was bubbling at all times. Thought to be all gas. After the test equipment was rigged down, we noticed that the 9 5/8 was giving back a little water. Max back 1 cup or so. Then welded on the 13 3/8 stub with the well head. The 9 5/8 is not straight and may have a little trouble getting the slips in the well head. Mud Data: Surveys: None Days S.S.: Getting caught up on dewatering, called in crew to clean tank bttms. Will clean as many as can. This is a confined space entry crew. One man to watch man in tank, along with tripod to winch him out if he goes down and a blower to blow fresh air into the tank at all times. This will be time consuming. Put the dewatering on a one man daylight operation until finished. None Daily Costs: $16,025 Well Costs: $118,025 28-Sep-99 Current Depth: Hole Drilled: Ave ROP: Operations Summary: install cellar & level loc, start to move rig at 1000 hfs, lay liner, mud boat, & set sub Page 1 Well Summary Report Well ID: Arco BLT #1 Ocean Energy Well Name: Arco BLT #1 29-Sep-99 30-Sep-99 01 -Oct-99 base and spot rig. Shut down for night. Rig is all on Icc except for pipe baskets and one mud pump and trailers. Crew worked 10 hrs. (24 hrs) Mud Data: None Surveys: None Days S.S.: Daily Costs: $15,425 Well Costs: $133,450 Current Depth: Hole Drilled: Ave ROP: Present Cps: drlg rat hole, Operations Summary: wait on daylight (7 hrs) miru. Mix spud mud to drl rathole (11 hrs) install 11 x 13 5/8 csg slips, had to run dc into 9 5/8 csg and tie rig up truck winch line around collar and pull 9 5/8 csg over to set slips., install 11 3m x 13 5/8 3 m tbg spool and test same. (5.5 hfs) drl rat hole (0.5 hrs) Comments: quite a chore to install the csg slips. But finally got them installed. Mud Data: None Surveys: None Days S.S.: Daily Costs: $23,325 Well Costs: $156,775 Current Depth: Hole Drilled: Ave ROP: Present Cps: drlg cmt at 278, had a weak spot at 205 - 225 then firm again, fell thru at 250 ft. Operations Summary: drlg rat hole w/mud motor (5 hfs) nu hope (10 hrs) test hope, 300 Iow, 3000 high, (4 hrs) install wear bushing (1 hfs) drlg cmt 25 - 100, using mud mtr (4 hrs) Mud Data: None Surveys: None Days S.S.: Daily Costs: $16,225 Well Costs: $173,000 Current Depth: Hole Drilled: Ave ROP: Present Cps: rib to 4081, cir out old mud, test csg, Operations Summary: drlg cmt w/mtr 100 - 298, good firm cmt to 205 then weak spot 205-225, then firm to 250 then fell thru to 284 to top of retainer (5 hfs) cir hole clean while ru BJ for pressure test. (1 hfs) pressure test 9 5/8 csg, test to 250 psi held steady for 10 min, bring to 500 and bled to 400 in 10 rain, bring to 770 bled to 550 in 10 min, bleed off 1/4 bbl back, less than .1 bbl lost while testing, bring up to 777 bled to 560 in 10 min. Bring to 1000 bled to 872 in 30 min. Bleed off, 1/4 bbl back, <.25 bbl lost during test. (2 hfs) blow down well with air, no apparent influx of gas or fluid (1 hfs) Page 2 Well Summary Report Well ID: Arco BLT #1 Ocean Energy Well Name: Arco BLT #1 02-Oct-99 03-Oct-99 monitor well for influx of gas or fluid, no gas to surface (1 hrs) blow down well, no fluid influx or gas to surface (0.25 hrs) fill hole with fresh water (0.25 hrs) drl cmt retainer at 284 w/mtr. (5 hrs) tih to 1724 tag up and drl on retainer, tih (6.5 hrs) lube & service rig (0.5 hrs) rih (1.5 hrs) Mud Data: None Surveys: None Days S.S.: Daily Costs: $21,425 Well Costs: $194,425 Current Depth: Hole Drilled: Ave ROP: Present Ops: rig released at 0600 hrs 10-3-99 Operations Summary: tih tag up at 4081 (3 hrs) cir (1.5 hfs) test csg to 1000 psi for 30 min. 1.25 bbls pumped, all but .3 back (1.5 hfs) clean mud tanks so can dispalce hole to 2% KCL (4 hrs) haul and mix 350 bbls 2% KCL fluid (affluient water from dewatering) (3 hfs) displace 11.2 mud in hole to 2% kcl water (1 hrs) Id dp & dc &mtr (6.5 hfs) nd bope, install 11" 3m blind flange, clean mud tanks (3.5 hfs) Comments: they are cleaning things up as they go along. Rig will be cleaner on stack out than when arrived. Mud Data: None Surveys: None Days S.S.: Daily Costs: $21,725 Well Costs: $216,150 Current Depth: Hole Drilled: Ave ROP: Operations Summary: nd, install 11" 3M blind flange on well head, clean mud tanks, rig released at 0600 hfs 10-3-99 (6 hrs) rd prepare rig to stack out in D&J Development yard (18 hfs) Mud Data: None Surveys: None Days S.S.: Daily Costs: $10,225 Well Costs: $226,375 Printed: 12:59 25-Apr-O0 Page 3 Daily Completion Report Well: Arco BLT#1 Arco BLT #1 Report No: 1 Ocean Energy 06:00 am 26-Sep-99 Operator: )cean Energy MD: Drilling Days: 'rVD: AFE No: PBTD: Authorized Amt: PBTVD: Daily Well Costs: Prey. Depth n/a Cum AFE Costs: Hole Made Daily Mud Costs: Drill Hrs: 0.0 Total Mud Costs: Avg. ROP: Last BOP Test: Wear Bushing In: [] Field: Pioneer Unit Completion Days: Rig Name: CHP Energy Days On Loc: 1 AFE No: DMW927C Authorized Amt: $504,000 Daily Well Costs: $102,000 Cum AFE Costs: $102,000 Daily Fluid Costs: Total Fluid Costs: Cum Well Costs: $102,000 Auth MD: Auth TVD: RKB to GL: RKB to ML: RKB to Csg Head: RKB to Tbg Head: Ground Elev: 113.00 13.00 10.75 100.00 Current Ops: rd, wait on loc, Planned Ops: work on rig, install well head on BLT Wellsite Supervisors: Dennis Ackerman Mud Engineer: Personnel: Oper: 0 Cont: 0 Svc: 0 Other:0 Total: 0 Toolpusher: Mike McNaughton No Tubular Information for this report. Casing, Next: TUBULAR INFORMATION Liner, Next: FLUIDS AND FILTRATION INFORMATION No Fluids and Filtration Records for this report. No Fluid Loss Pills Records for this report. FLUID LOSS PILLS PACKER DATA No Packer Records for this report. PERFORATION DATA No Perforation Records for this report. From 8:00 OPERATIONS SUMMARY Non- To Elapsed Code Prod Operations Description 0:00 16.00 R/D rd prepare to move, move mud tanks off loc to clean up liner Daily Completion Report Well: Arco BLT#1 Arco BLT #1 Report No: 2 Ocean Energy 06:00 am 27-Sep-99 Operator: )cean Energy MD: Drilling Days: 'i'VD: AFE No: PBTD: Authorized Amt: PBTVD: Daily Well Costs: Prev. Depth n/a Cum AFE Costs: Hole Made Daily Mud Costs: Drill Hfs: 0.0 Total Mud Costs: Avg. ROP: Last BOP Test: Wear Bushing In: [] Field: Pioneer Unit Completion Days: 1 Rig Name: CHP Energy Days On Loc: 2 AFE No: DMW927C Authorized Amt: $504,000 Daily Well Costs: $16,025 Cum AFE Costs: $118,025 Daily Fluid Costs: $600 Total Fluid Costs: $600 Cum Well Costs: $118,025 Auth MD: Auth TVD: RKB to GL: RKB to ML: RKB to Csg Head: RKB to Tbg Head: Ground Elev: 113.00 13.00 10.75 100.00 Current Ops: Planned Ops: put loc back together, install dead men. And move rig, will move at least all permit loads tomorrow. Wellsite Supervisors: Dennis Ackerman Toolpusher: Mike McNaughton Mud Engineer: Personnel: Oper: 1 Cont: 5 Svc: 2 Other: 0 Total: 8 No Tubular Information for this report. Casing, Next: TUBULAR INFORMATION Liner, Next: FLUIDS AND FILTRATION INFORMATION No Fluids and Filtration Records for this report. No Fluid Loss Pills Records for this report. FLUID LOSS PILLS PACKER DATA No Packer Records for this report. PERFORATION DATA No Perforation Records for this report. From 0:00 OPERATIONS SUMMARY Non- To Elapsed Code Prod Operations Description 0:00 24.00 DMOB general rig down, clean up loc. Pu liner, prepare for rig move. Rig crew worked 8 hrs today Daily Completion Report Well: Arco BLT #1 Arco BLT #1 Report No: 2 Ocean Energy 06:00 am 27-Sep-99 No BHA/VVorkstring Details for this report. WORKSTRING INFORMATION No Safety Information for this report. SAFETY LOGISTICS No Logistics Information for this report. BOAT, TUG & BARGE STATUS No Boat Status Details for this report. Rig Name: CHP Energy Equipment Problems: Location Condition: Sky: pc Vis.: 25 RIG/WEATHER INFORMATION RKB Elevation: Temp: 50.0 Pressure: Wind: / Gusts: Swell Ht/Dir: / Wave Ht: COMMENTS the tested 9 5/8 csg, to 1000 psi drop to 200 psi in 10 min., No visible leaks from csg collar where it was welded solid. Could not dectect any water infux in the 13 3/8 x 9 5/8 annulus. Pumped max 3 gals fluid, the 13 3/8 x 9 5/8 annulas was bubbling at all times. Thought to be all gas. After the test equipment was rigged down, we noticed that the 9 5/8 was giving back a little water. Max back 1 cup or so. Then welded on the 13 3/8 stub with the well head. The 9 5/8 is not straight and may have a little trouble getting the slips in the well head. Getting caught up on dewatering, called in crew to clean tank bttms. Will clean as many as can. This is a confined space entry crew. One man to watch man in tank, along with tripod to winch him out if he goes down and a blower to blow fresh air into the tank at all times. This will be time consuming. Put the dewatering on a one man daylight operation until finished. Daily Report Well ID: Anco BLT ~'1 Report No: 3 Ocean Energy Well Name: Area BLT #1 Report for 24:00 hm 28-,.~ep-~9 AFE Nos: DMW@27C- Rig Name; Spud Date: Days: Since Spud: Measured Depth: Previous Report Depth: Drill Hfs: Last Casing: Personnel: Operator: Current Operations: plannect Oper~ons: Toolpusher.' WellsJte $upervjsor~: )r, ean Energy CNP Energy On Loeatlotl; 3 Field: Total Well Coef~: Total Daily Costs: Mud Costs: From To Elapsed 0:0O 0;00 24,00 R/U 0 Next: 1 Contractor: g Service: Total: Total Ve~=al Depth; Hole Made: Average ROP: Last BOP Test: 3 Othen 0 Total: finish to ru tomorr~v, In.~tail slips end tbg spool, drl rat hole Mike McNaugMton Dennis Ankerman Operations Summary Code Operations Description Pioneer Unit $800 install cellar & level k~c, start :o move rig at t000 bm, lay iiner, mud boat, & set suD base and spot rig. 8hut down for nigMt, Rig Is all on Icc except for pipe basicats and one mud purr~ and trailers. Crew wortced t0 13 Weather Sky Condition: Air Temperature: Wind Speed/Db: rain, sleet, light snow, sun Oeo F / Visibility: Bar. Pressure: Wind Gusts: Daily Report Well ID: Arco BLT ~I Report No: 4 ___ i ii i .... Operator: AFENos; DMW~27C-$504,000 Ri~ Name: Spud Data; Measu~d ~ra~ous Repo~ Dep~ Drill H~ Last C~ing: Pem~ne~: Planned Toelpusher: Wells!ts Supe~tsom: Fram To 0;00 7:00 7:00 18:00 15',0~ 23;30 : , · Elapsed Code 7.Q0 11.20 R/U 5,50 NU/ND , -. )caen Energy CHP Energy On Location: 4 Ocean Energy Well Name: Arco BLT Report fei' 24:00 hm 2~t-Sep.99 Reid: Pioneer Unit Tot=l Well Costs; $156,775 Total Daffy Costs: ~23,325 Mud Costs; SD To~I: Total VeStal Depth: Hole Made: 0 Average ROP: Next: Last BOP Test: I co~.tr'actor: 11 Se,,vi~e= 5 off]er: 0 Total: 17 drl~; res hole, 23:30 0:O0 0,50 OTHER i finish rat hots, nu bop, test m 3000 psi, drlg out ~mt w/8,5 bit, Plan an using to drl at least the first kelly dawn, Mike M~Waughton Dennis A~n ~ ~e~ns Summa~ . . Operations D~aHptlon ~it on daylight mira. Miz ~ mud to drl r~ole install 11 x 13 ~ csg ~ips, h~ to r~ de in~o ~ 5/8 ~g and tie dg up ~ winch II~e around ~llar and pull 9 5/8 ~sg over to ~t sfas., in~{I 11 ~ x 13 5/8 3 m tbg spool and test same. dd rat hole r--= ' , Commen~ ....... quite a chore to {nstall the csg slips, aut finally got them installed, Rig Name'. CHP Energy = · - i L'. . ~ -- Fimt Alcl: 0 Medicsh 0 A~ident Description: Meetings/Drill~ Time I:~scripflon ~ BOP Test , i _, Sky Condtl~on: rah Air Temperature: 35,0 deg .~ Wind Speedlolr: / Prir~ted: 6:32. 30.$ep.99 Rig Information _. · RKB Elevatlon; ft Safety Infarmation ......... Lo$~ Time A~idents: 0 Days Sin=e LTA; -J Crownarnati~ Cheek Weather ,. . Visibility; Bar, Press[tm: Wind Gusts: Pr Page 1 Daily Report Well ID: Arco BLT #'1 Report No: 5 Opera;or. AFE Noc: DMW927C- $504,000 Rig Name: Spud Date; Day~: ,Since ~pud: Measured Depth: Pmvioue Report Depth: Drill Last Casing: Pemonnei~ oparator; cur~nt Operations; P/armed Operations; Toolpuaher: Wellsite Supervisors: )coon Energy Clip Energy On L~oafion: 6 Ocean Energy Well Name: Arco BLT #t Repor~ for 24:00 hrs 30-~ep,99 Field: Pioneer Unit Total Well Cost. s: $173,000 Total Daily Costs: $16,225 Mud Costs; ~D Total: $600 Total Vertical Depth: Hole 0 Average ROI=: Next: Last BOP Test: I Contractor: 11 Service: 0 Other; 0 Total: 12 drlg cmt at 27a, had a week spot at 205 - 225 then firm again, fell thru at 250 drl~ cml to retainer test csg to 1000 psi, blc~w down well for nag test. Brian Busby Dennis Ar..kerman Operations Summary Fram To Elapsed Code 0:O0 5:00 5.00 OTHER 5:00 15:00 10.00 NU/ND 15:00 19:00 4,00 BQPOT IB:O0 20:00 1.00 NUtND 2O;0C' 0;00 4.00 CMTD Opemtiorm Description drtg rat hole w/mud motor nu hope teat hope, 300 Iow, 3000 high, install wear bushing ddg ~mt 25 - I00, u~ng rrtud mtr Hook Loads (lbs): Miscellaneous Drilling Parametem Off Bottom Rotate; 2~ Pi~ Up: 20 ,Slack Off:, 20 ~ Wear Btmhing Installed Hole No Run Ma~e Mode[ Diem Made ~ 1 STC SDGH 8.500 7,5 Rig Name: CHP Energy hooation Conclltion wet, muddy Fimt Aid: O Medical: 0 Acci~nt Maetin~/D~lls Ti~e Description ~ BOP Sky Condition= rain Air Temperature: 3~,0 dog F Wind Speed/Din / Hr~ Bit Information R,O,P, W,O,B. P,.P.M. Torque Mucl Avg Max Ava Max Ava Max Av9 Wt 25.0 10 12 83 8,50 Rig Information - RKB Elevation: 13 Puml0 Flow Pree~ Safety Information ................ Lost ~me Accidents: 0 Deys Slnae LTA: 62 ~ Crownamaflc Check WeaU~er Vis~ilih,: Bar. Pm~sure; Wind Guam: Page 1 Daily Completion Report Well: Arco BLT#1 Arco BLT #1 Report No: 6 Ocean Energy 06:00 am 01-Oct-99 WORKSTRING INFORMATION No Work String Details for this report BHA Description: DC,DC,DC,DC,XO,XO,MMTR,BIT = 143.96 No Safety Information for this report. SAFETY LOGISTICS No Logistics Information for this report. BOAT, TUG & BARGE STATUS No Boat Status Details for this report. No Rig Information for this report. Sky: rain Vis.: 1 Temp: 35.0 RIG/WEATHER INFORMATION Pressure: Wind: / Gusts: Swell HtJDir: / Wave Ht: No comments for this report. COMMENTS Daily Completion Report Well: Arco BLT #1 Arco BLT #1 Report No: 6 Ocean Energy 06:00 am 01-Oct-99 Operator: )cean Energy MD: Drilling Days: TVD: AFE No: PBTD: Authorized Amt: PBTVD: Daily Well Costs: Prey. Depth n/a Cum AFE Costs: Hole Made Daily Mud Costs: Drill Hrs: 0.0 Total Mud Costs: Avg. ROP: Last BOP Test: Wear Bushing In: [] Field: Pioneer Unit Completion Days: 5 Rig Name: CHP Energy Days On Loc: 6 AFE No: DMW927C Authorized Amt: $504,000 Daily Well Costs: $21,425 Cum AFE Costs: $194,425 Daily Fluid Costs: Total Fluid Costs: $600 Cum Well Costs: $194,425 Auth MD: Auth TVD: RKB to GL: RKB to ML: RKB to Csg Head: RKB to Tbg Head: Ground Elev: 113.00 13.00 10.75 100.00 Current Ops: rih to 4081, cir out old mud, test csg, Planned Ops: test csg to 1000 psi, clean mud tanks, displace hole w/2% KCL, pooh sideways, rd. Wellsite Supervisors: Dennis Ackerman Toolpusher: Brian Busby Mud Engineer: Personnel: Oper: 1 Cont: 10 Svc: 0 Other:0 Total: 11 No Tubular Information for this report. Casing, Next: TUBULAR INFORMATION Liner, Next: FLUIDS AND FILTRATION INFORMATION No Fluids and Filtration Records for this report. No Fluid Loss Pills Records for this report. FLUID LOSS PILLS PACKER DATA No Packer Records for this report. PERFORATION DATA No Perforation Records for this report. From 0:00 5:O0 6:00 OPERATIONS SUMMARY Non- To Elapsed Code Prod Operations Description 5:00 5.00 CMTD drlg cmt w/mtr 100 - 298, good firm cmt to 205 then weak spot 205-225, then firm to 250 then fell thru to 284 to 6:00 1.00 CRCF 8:00 2.00 PRTS 8:00 9:00 1.00 OTHER 9:00 10:00 1.00 MONFC 10:00 10:15 0.25 OTHER 10:15 10:30 0.25 CFCO 10:30 15:30 5.00 CLN 15:30 22:00 6.50 TIH 22:00 22:30 0.50 SERV 22:30 0:00 1.50 TIH top of retainer cir hole clean while ru BJ for pressure test. pressure test 9 5/8 csg, test to 250 psi held steady for 10 rain, bring to 500 and bled to 400 in 10 rain, bring to 770 bled to 550 in 10 rain, bleed off 1/4 bbl back, less than .1 bbl lost while testing, bring up to 777 bled to 560 in 10 min. Bring to 1000 bled to 872 in 30 min. Bleed off, 1/4 bbl back, <.25 bbl lost during test. blow down well with air, no apparent influx of gas or fluid monitor well for influx of gas or fluid, no gas to surface blow down well, no fluid influx or gas to surface fill hole with fresh water drl cmt retainer at 284 w/mtr. tih to 1724 tag up and drl on retainer, tih lube & service rig rih Daily Completion Report Well: Arco BLT#1 Arco BLT #1 Report No: Ocean Energy 06:00 am 02-Oct-99 WORKSTRING INFORMATION No Work String Details for this report BHA Description: DC,DC,DC,DC,XO,XO,MMTR,BIT -- 143.96 First Aid: 0 Lost Time Accidents: Accident Desc: [] BOP Test Medical: 0 Days Since LTA: 64 [] Crownamatic Check SAFETY Meetings/Drills Safety: Abandon Ship: Fire: Man-Over-Brd: BOP Pit: Trip: Time Description LOGISTICS No Logistics Information for this report. BOAT, TUG & BARGE STATUS No Boat Status Details for this report. No Rig Information for this report. Sky: rain Vis.: 4 Temp: 35.0 RIG/WEATHER INFORMATION Pressure: Wind: / Gusts: Swell Ht/Dir: / Wave Ht: COMMENTS they are cleaning things up as they go along. Rig will be cleaner on stack out than when arrived. Daily Completion Report Well: Arco BLT#1 Arco BLT #1 Report No: 7 Ocean Energy 06:00 am 02-Oct-99 Operator: )cean Energy MD: Drilling Days: TVD: AFE No: PBTD: 4081 Authorized Amt: PB'I'VD: 4081 Daily Well Costs: Prey. Depth n/a Cum AFE Costs: Hole Made Daily Mud Costs: Drill Hrs: 0.0 Total Mud Costs: Avg. ROP: Last BOP Test: Wear Bushing In: [] Field: Pioneer Unit Completion Days: 6 Rig Name: CHP Energy Days On Loc: 7 AFE No: DMW927C Authorized Amt: $504,000 Daily Well Costs: $21,725 Cum AFE Costs: $216,150 Daily Fluid Costs: Total Fluid Costs: $600 Cum Well Costs: $216,150 Auth MD: Auth TVD: RKB to GL: RKB to ML: RKB to Csg Head: RKB to Tbg Head: Ground Elev: 113.00 13.00 10.75 100.00 Current Ops: rig released at 0600 hrs 10-3-99 Planned Ops: rd, clean up rig, lower shaker to oringal height and put deander to orginal positon Wellsite Supervisors: Dennis Ackerman Toolpusher: Brian Busby Mud Engineer: Personnel: Oper: 1 Cont: 9 Svc: 0 Other: 0 Total: 10 No Tubular Information for this report. Casing, Next: TUBULAR INFORMATION Liner, Next: FLUIDS AND FILTRATION INFORMATION No Fluids and Filtration Records for this report. No Fluid Loss Pills Records for this report. PACKER DATA No Packer Records for this report. FLUID LOSS PILLS PERFORATION DATA No Perforation Records for this report. From 0:00 3:00 4:30 1.50 CRCF 4:30 6:00 1.50 PRTS 6:00 10:00 4.00 OTHER 10:00 13:00 3.00 OTHER 13:00 14:00 1.00 CRCF 14:00 20:30 6.50 PU/LD 20:30 0:00 3.50 NU/ND OPERATIONS SUMMARY Non- To Elapsed Code Prod Operations Description 3:00 3.00 TIH tih tag up at 4081 cir test csg to 1000 psi for 30 min. 1.25 bbls pumped, all but .3 back clean mud tanks so can dispalce hole to 2% KCL haul and mix 350 bbls 2% KCL fluid (affluient water from dewatering) displace 11.2 mud in hole to 2% kcl water Id dp & dc & mtr nd bope, install 11" 3m blind flange, clean mud tanks Daily Completion Report Well: Arco BLT#1 Arco BLT #1 Report No: 8 Ocean Energy 06:00 am 03-Oct-99 Operator: )cean Energy MD: Drilling Days: 'I-VD: AFE No: PBTD: 4081 Authorized Amt: PBTVD: 4081 Daily Well Costs: Prev. Depth n/a Cum AFE Costs: Hole Made Daily Mud Costs: Drill Hrs: 0.0 Total Mud Costs: Avg. ROP: Last BOP Test: Wear Bushing In: [] Field: Pioneer Unit Completion Days: 7 Rig Name: Days On Loc: 8 AFE No: DMW927C Authorized Amt: $504,000 Daily Well Costs: $10,225 Cum AFE Costs: $226,375 Daily Fluid Costs: Total Fluid Costs: $600 Cum Well Costs: $226,375 CHP Energy Auth MD: Auth TVD: RKB to GL: RKB to ML: RKB to Csg Head: RKB to Tbg Head: Ground Elev: 113.00 13.00 10.75 100.00 Current Ops: Planned Ops: Wellsite Supervisors: Mud Engineer: Personnel: Oper: 1 Dennis Ackerman Cont: 9 Svc: 0 Other:0 Total: 10 Toolpusher: Brian Busby No Tubular Information for this report. Casing, Next: TUBULAR INFORMATION Liner, Next: FLUIDS AND FILTRATION INFORMATION No Fluids and Filtration Records for this report. No Fluid Loss Pills Records for this report. FLUID LOSS PILLS PACKER DATA No Packer Records for this report. PERFORATION DATA No Perforation Records for this report. From To Elapsed Code 0:00 6:00 6.00 NU/ND 6:00 0:00 18.00 R/D OPERATIONS SUMMARY Non- Prod Operations Description nd, install 11" 3M blind flange on well head, clean mud tanks, rig released at 0600 hrs 10-3-99 rd prepare rig to stack out in D&J Development yard Daily Completion Report Well: Arco BLT#1 Arco BLT #1 Report No: 8 No BHA/Workstring Details for this report. WORKSTRING INFORMATION No Safety Information for this report. SAFETY LOGISTICS No Logistics Information for this report. BOAT, TUG & BARGE STATUS No Boat Status Details for this report. No Rig Information for this report. No Weather Information for this report. RIG/WEATHER INFORMATION No comments for this report. COMMENTS Ocean Energy 06:00 am 03-Oct-99 OCEAN ENERGY Well: PIONEER UNIT ARCO BLT#1 Location: SEC 22 T17N R3W Date: 10/18/99 Work Done on' 10/17/99 Present Operation: RIH W/PACKER AND TBG DALLY RIG REPORT Perfs: 3902-08' 3913-40' TD/PBTD: 4092 KB/GL 100/130' Others: Operations Planned: TEST LOWER PERFS Time From To DAILY OPERATIONS 10/17/99 POOH W/TBG. LD BIT AND SCRAPER RU BAKER ATLAS WIRELINE EQUIPMENT PERFORATE ZONE 1 3913' TO 3940' 3902' TO 3908' 165 HOLES 5 JSPF 4 1/2" ALPHA JET CASING GUN 135/45 DEGREE PHASING 32 GRAM .45" HOLES RDMO ATLAS WIRELINE PU BAKER RETRIEVAMATIC PACKER AND 2.205" ID XN NIPPLE. RIH W/30 JTS TBG. SWIFN COSTS PREVIOUS DAILY CUMULATIVE [Rig $101,635 $5,250 $106,885 Supervision $11,950 $750 $12,700 Rentals $18,350 $600 $18,950 Roustabouts $4,100 $0 $4,100 Transportation $110,100 $0 $110,100 Cement, Acid, Frac. $0 $0 Perforating, Logging $8,000 $6,413 $14,413 Subsurface Pumps $0 Rods, Scrapers $0 Tubing, Subs, SN $24,600 $0 $24,600 TAC, Packer, Repair $4,800 $4,800 Others $16,500 $0 $16,500 Location $750 $0 $750 Misc. $13,075 $0 $13,075 El ectrical/Fu el $5,900 $0 $5,900 Water $2,800 $450 $3,250. Contingency $31,776 $1,826 $33,602. TOTAL $349,536 $20,089 $369,625 OCEAN ENERGY RESOURCES, INC. PIONEER UNIT ARCO BLT#1 Location' SEC 22 T17N R3W Date: 10/19/99 Work Done on: 10/18/99 Present Operation: FLOW AND SWAB TEST LOWER PERFS Perfs: TD/PBTD: KB/GL Others: DALLY RIG REPORT 3902-08' 3913-40' 4092 100/130' Operations Planned: INJECTION TEST Time From To DALLY OPERATIONS 10/18/99 SlTP/CP 100 PSI FINISH TIH W/TBG AND PACKER SET RETRIEVAMATIC PACKER @ 3836' W/10,000# COMPRESSION FILL ANNULUS W/15 BBL 2% KCL WATER. RU TO SWAB TBG BEGAN FLOWING 20 MINUTES AFTER SETTING PACKER ESTIMATED 127 BBL FLUID ENTRY IN 14 HOURS FLOWED WELL TO TANK FOR 2 1/2 HRS. RECOVERED 10 BBL FLUID. SWAB TO TANK FOR 3 HRS. RECOVERED 77 BBL FLUID FFL 2750'. FINAL SWAB RATE 25 BPH SWIFN SENT SAMPLE OF SWAB FLUID TO LAB FOR ANALYSIS ~87 BBL TOTAL FLUID RECOVERED FOR DAY COSTS PREVIOUS DAILY CUMULATIVE Rig $106,585 $4,125 $110,710 Supervision $12,700 $750 $13,450 Rentals $18,950 $600 $19,550 Roustabouts $4,100 $0 $4,100 Transportation $110,100 $0 $110,100 Cement, Acid, Frac. $0 $0 Perforating, Logging $14,413 $0 $14,413 Subsurface Pumps $0 Rods, Scrapers $0 Tubing, Subs, SN $24,600 $0 $24,600 TAC, Packer, Repair $4,800 $0 $4,800 Others $16,500 $0 $16,500 Location $750 $0 $750 Misc. $13,075 $0 $13,075 Electrical/Fuel $5,900 $0 $5,900 Water $3,250 $520 $3,770 Contingency $33,5721 $600 $34,172 TOTAL $369,295 $6,595 $375,890, OCEAN ENERGY Well: PIONEER UNIT ARCO BLT#1 Location' SEC 22 T17N R3W Date: 10/20/99 Work Done on' 10/19/99 Present Operation: PUMP INJECTIVITY TEST DALLY RIG REPORT Perfs: 3902-08' 3913-40' TD/PBTD: 4092 KB/GL 100/130' Others: Operations Planned: RUN PRESSURE SURVEY Time From To DAILY OPERATIONS 10/19/99 SITP 380 PSI . , BLED WELL OFF IN 1 MINUTE. FLAMMABLE GAS TO SURFACE FLOWING WATER IMMEDIATELY AFTER GAS BLEEDOFF RU SWAB EQUIPMENT SWAB TO TANK FOR 6 HRS RECOVERED 126 BBL FLUID FFL 2700' FINAL RATE 19.6 BPH SWIFN COSTS PREVIOUS DAILY CUMULATIVE Rig $110,710 $2,540 $113,25.0i Supervision $13,450 $750, $14,200 Rentals $19,550 $600 $20,150 Roustabouts $4,100 $0 $4,100 Transportation $110,100 $0 $110,10~) Cement, Acid, Frac. $0 $0 Perforating, Logging $14,413 $01 $14,413 Subsurface Pumps $0 Rods, Scrapers $0 Tubing, Subs, SN $24,600 $0 $24,600 TAC, Packer, Repair $4,800 $0 $4,800 Others $16,500 $0 $16,500 Location $750 $0 $750 Misc. $13,075 $0 $13,075 Electrical/Fuel $5,900 $0 $5,900 Water $3,770 $520 $4,290 Contingency $34,172 $441 $34,613 TOTAL $375,890 $4,851 $380,741 OCEAN ENERGY Well: PIONEER UNIT ARCO BLT#1 Location: SEC 22 T17N R3W Date: 10/21/99 Work Done on' 10/20/99 Present Operation: PRESSURE SURVEY DAILY RIG REPORT Perfs: 3902-08' 3913-40' TD/PBTD: 4092 KB/GL 100/130' Others: Operations Planned: Time From To DAILY OPERATIONS 10/20/99 SITP 450 PSI BLED WELL OFF IN 1 MINUTE. FLAMMABLE GAS TO SURFACE FLOWING WATER IMMEDIATELY AFTER GAS BLEEDOFF RU SWAB EQUIPMENT MADE 1 SWAB RUN FROM 1100'. CHANGE WELLHEAD VALVE RU BAKER ATLAS WIRELINE. RIH W/PRESSURE RECORDERS SET RECORDERS AT 3915'. PUMP 4 STEP INJECTION SURVEY 30 BBL TOTAL 2% KCL WATER AS FOLLOWS: 1/2 BPM @ 600 PSI 1 BPM ~ 900 TO 1000 PSI 1.5 BPM @ 1400 TO 1450 PSI 2 BPM @ 1850 TO 2000 PSI ISlP 1500 PSI ISWl AND RECORD BOTTOM HOLE PRESSURES. COSTS PREVIOUS DAILY CUMULATIVE Rig $113,250 $3,500 $116,75'0 Supervision $14,200 $750 $14,950 Rentals $20,150 $600 $20,750 Roustabouts $4,100 $0 $4,100 Transportati.on $110,100 $0 $110,100 Cement, .Acid, Frac. $0 $0 Perforating, Logging $14,413 $5,000 $19,413 Subsurface Pumps $0 Rods, Scrapers $0 Tubing, Subs, SN $24,600 $0 $24,600 TAC, Packer, Repair' $4,800 $0 $4,8~0 Others $16,500 $0 $16,500 Location $750 $0 $750 ! Misc. $13,075 $0 $13,075 !Electrical/Fuel $5,900 $0 $5,900 Water $4,290 $0 $4,290 Contingency $34,613 $985 $35,598 TOTAL $380,741 $10,835 $391,576 OCEAN ENERGY Well: Location: DAILY RIG REPORT Date: Work Done on: Present Operation' PIONEER UNIT ARCO BLT#1 Perfs: 3902-08' 3913-40' SEC 22 T17N R3W TD/PBTD: 4092 10/22/99 KB/GL 100/130' 10/21/99 Others: PRESSURE SURVEY Operations Planned: Time From To DAILY OPERATIONS 10/21/99 ATLAS WIRELINE PRESSURE RECORDERSET AT 3915' HOUR PRESS TEMP HR PRESS TEMP 0 3200 80 1 2149.7 89.07 19 2028.7 93.99 2 2071.9 90.42 20 2029.6 94.02 3 2050.2 91.23 21 2030.1 94.04 4 2040 91.72 22 2030.5 94.11 5 2034.3 92.13 23 2030.9 94.11 6 2030.9 92.42 24 2031.3 94.17 7 2028.8 92.69 25 2031.6 94.23 8 2027.6 92.88 26 2031.4 94.24 9 2026.9 93.07 27 2031.8 94.25 10 2026.6 93.21 28 2032.1 94.31 11 2026.5 93.35 29 2032.3 94.31 12 2026.6 93.44 30 2032.7 94.33 13 2027 93.58 31 2033 94.36 14 2026.8 93.64 32 2033.3 94.39 15 2027.3 93.72 33 2033.6 94.38 16 2027.6 93.81 34 2034 94.42 17 2028 93.86 35 2034.3 94.43 18 2028.3 93.91 36 2034.5 94.42 COSTS PREVIOUS DAILY CUMULATIVE Rig $116,750 $1,310 $118,060 Supervision $14,950 $750 $15,700 Rentals $20,750 $600 $21,350 Roustabouts $4,100 $0 $4,100 Transportation $110,100 $0 $110,100 Cement, Acid, Frac. $0. $0 Perforating, Logging $19,413 $0 $19,413 Subsurface Pumps $0 Rods, Scrapers $0 Tubing, Subs, SN $24,600 $0 $24,600 TAC, Packer, Repair $4,800 $0 $4,800 Others $16,500 $0 $16,500 Location $750 $0 $750 Misc. $13,075 $0 $13,075 Electrical/Fuel $5,900 $0 $5,900 Water $4,290 $0 $4,290 !Contingency $35,598 $266 $35,864 TOTAL $391,576 $2,926 $394,502 OCEAN ENERGY Well: PIONEER UNIT ARCO BLT#1 Location: SEC 22 T17N R3W Date: 10/23/99 Work Done on: 10/22/99 Present Operation: PULL PACKER DALLY RIG REPORT Perfs: 3902-08' 3913-40' TD/PBTD: 4092 KB/GL 100/130' Others: Operations Planned: SET PERMANENT PACKER PERFORATE ZONE 2 Time From To DAILY OPERATIONS 1 O/22/99 ATLAS WIRELINE PRESSURE RECORDERSET AT 3915' HOUR PRESS TEMP HR PRESS TEMP 36 2034.5 94.42 48 2038.5 94.57 RETRIEVE PRESSURE SURVEY TOOLS SWIFN " COSTS PREVIOUS DAILY CUMULATIVE 'Rig $118,060 $1,310 $119,370 Supervision $15,700 $750 $16,450 Rentals $21,350 $600 $21,950 Roustabouts $4,100 $0 $4,100 Transportation $110,100 $0 $110,100 Cement, Acid, Frac. $0 $0 Perforating, Logging $19,413 $0 $19,413 Subsurface Pumps $0 Rods, Scrapers $0 Tubing, Subs, SN $24,600 $0 $24,600 TAC, Packer, Repair $4,800 $0 $4,8(~U Others $16,500 $0 $16,500 Location $750 $0 $75d' Misc. $13,075 $0 $13,075 El ectrical/Fu el $5,900 $0 $5,900 Water $4,290 $0 $4,290 Contingency $35,864 $266 $36,130 TOTAL $394,502 $2,926 $397,428 OCEAN ENERGY PIONEER UNIT ARCO BLT#1 Location: SEC 22 T17N R3W Date: 10/24/99 Work Done on' 10/23/99 Present Operation: SD WAIT FOR PACKER PARTS Perfs: TD/PBTD: KB/GL Others: DALLY RIG REPORT 3902-08' 3913-40' 4O92 100/130' Operations Planned' SET PERMANENT PACKER PERFORATE ZONE 2 Time From To DAILY OPERATIONS 10/23/99 SITP 300 PSI BLED DOWN TBG. RELEASE PACKER POOH W/TBG. LD RETRIEVAMATIC PACKER. RIH W/25 JTS TBG. AND XN NIPPLE SWIFN COSTS PREVIOUS DAILY CUMULATIVE IRig $119,370 $2,310 $121,680 I Su pervision $16,450, $750 $17,200 Rentals $21,950 $600 $22,550 Roustabouts $4,100 $0 $4,100 Transportation $110,100 $0 $110,100 Cement, Acid, Frac. $0 $0 Perforating, Logging $19,413 $0 $19,413 Subsurface Pumps $0 Rods, Scrapers $0 Tubing, Subs, SN $24,600 $0 $24,600 TAC, Packer, Repair $4,800 $0~ $4,800 Others $16,500 $0 $16,500 Location $750 $01 $750 Misc. $13,075 $0 $13,075 Electrical/Fuel $5,900 $0 $5,900 Water $4,290 $0 $4,290 Continge,~c¥ $36,130 $366 $36,496 TOTAL $397,428 $4,026 $401,454 OCEAN ENERGY PIONEER UNIT ARCO BLT#1 Location: SEC 22 T17N R3W D ate: 10/25/99 Work Done on: 10/24/99 Present Operation: RUN PERMANENT PACKER DAILY RIG REPORT Perfs: 3902-08' 3913-40' TD/PBTD: 4092 KB/GL 100/130' Others: Operations Planned: PERFORATE AND TEST ZONE 2 Time From To DAILY OPERATIONS 10~24~99 SD WAIT FOR PACKER PARTS . , .. .... COSTS PREVIOUS DAILY CUMULATIVE Rig $121,680 $1,310 $122,990 Supervision $17,200 $0 $17,200 Rentals $22,550 $600 $23,150 Roustabouts $4,100 $0 $4,100 Transportation $110,100 $0 $110,100 Cement, Acid, Frac. $0 $0 Perforating, Logging $19,413 $0 $19,413 Subsurface Pumps $0 Rods, Scrapers $0 Tubing, Subs, SN $24,600 $0 $24,600 TAC, Packer, Repair $4,800 $0 $4,800 Others $16,500 $0 $16,500 Location $750 $0 $750 Misc. $13,075 $0 $13,075 Electrical/Fuel $5,900 $0 $5,900, Water $4,290 $0 $4,290 Contingency $36,496 $191 $36,687 TOTAL $401,454 $2,101 $403,555 OCEAN ENERGY Well: PIONEER UNIT ARCO BLT#1 Location: SEC 22 T17N R3W Date: 10/26/99 Work Done on: 10/25/99 Present Operation: SWAB DOWN TBG. PREP TO PERFORATE. Perfs: TD/PBTD: KB/GL Others: DALLY RIG REPORT 3902-08' 3913-40' 4092 100/13O' Operations Planned: PERFORATE AND TEST ZONE 2 Time From To DAILY OPERATIONS 1 O/25/99 SITP 3OO PSI. BD TBG. POOH W/TUBING. RU ATLAS WIRELINE. RIH W/BAKER MODEL D PERMANENT PACKER W/FLAPPER VALVE ASSEMBLY. SET PACKER AT 3840'. POOH RD WIRELINE. SWIFN. ., .. .. --, ., COSTS PREVIOUS DAILY CUMULATIVE ~l~i9 $122,990 $5,250 $128,240 .Supervision $17,200 $750 $17,950 Rentals $23,150 $600 $23,750 'Roustabouts $4,100 $0 $4,100 ~ransportation $110,100 $0 $110,100 :_Cement, Acid, Frac. $0i $0 Perforating, Log~in~l $19,413 $3,360 $22,773 Subsurface Pumps $0 Rods, Scrapers $0 Tubing, Subs, SN $24,600 $0 $24,600 _TAC, Packer. Repair $4,800 $5,800 $10,600 Others $16,500 $0 $16,500 Location $750 $0 $750 Misc. $13,075 $0 $13,075 Electrical/Fuel $5,900 $0 $5,900, Water $4,290 $1,550 $5,840 'Contingency $36,687 $1,731 $38,418 TOTAL $403,555 $19,041 $422,596 OCEAN ENERGY . sou.c s, INC. PIONEER UNIT ARCO BLT#1 Location: SEC 22 T17N R3W Date: 10/27/99 Work Done on: 10/26/99 Present Operation' PERFORATE ZONE 2 DAILY RIG REPORT Perfs: 3902-08' 3913-40' TD/PBTD: 4092 KB/GL 100/130' Others: Operations Planned' RUN PKR AND TEST ZONE 2 Time From To DAILY OPERATIONS 10/26/99 PU BAKER F LATCH PLUG ASSEMBLY AND TIH W/TBG. LATCH INTO MODEL D PACKER AT 3840'. UNLATCH F LATCH PLUG ASSEMBLY. LD 1 JT TBG. SWAB FL TO 2000'. TOOH W/TBG. SWIFN. COSTS PREVIOUS DAILY CUMULATIVE Rig $128,240 $5,075 $133,315 Supervision $17,950 $750 $18,700 Rentals $23,750 $600 $24,350 Roustabouts $4,100 $0 $4,100 Transportation $110,100 $0 $110,100 Cement, Acid, Frac. $0 $0 Perforating, Logging $22,7731 $0 $22,773 Subsurface Pumps $0 Rods, Scrapers $0 Tubing, Subs, SN $24,600, $0 $24,600 TAC, Packer, Repair $10,600~ $3,450 $14,050 Others $16,500 ~ $0 $16,500 Location $7501 $0 $75(~ Misc. $13,0751 $0 $13,075 Electrical/Fuel $5,900 $0 $5,900 Water $5,840 $520 $6,360 Contingency $38,418 $1,040 $39,457 TOTAL $422,596 $11,435 $434,030 OCEAN ENERGY PIONEER UNIT ARCO BLT#1 Location' SEC 22 T17N R3W Date: 10/28/99 Work Done on' 10/27/99 Present Operation: TEST ZONE 2 DALLY RIG REPORT Perfs: 3902-08' 3913-40' TD/PBTD: 4092 KB/GL 100/130' Others: Operations Planned: Time From To DAILY OPERATIONS 1 O/27/99 SICP 0 PSi RU BAKER ATLAS WIRELINE EQUIPMENT PERFORATE ZONE #2 2732-72' 5 JSPF 4 1/2" ALPHA JET CASING GUNS. NO FLUID ENTRY WHILE PERFORATING RD BAKER ATLAS PU BAKER 9 5/8" RETRIEVAMATIC PACKER AND 2.205" ID XN NIPPLE. RIH W/86 JTS 2 7/8" J-55 6.3# EUE TBG SET PACKER AT 2684' W/10,000# COMPRESSION FILL ANNULUS AND TEST TO 500 PSI RU TO SWAB. IFL 1850' SWAB TO XN NIPPLE AT 2684' AND MADE 2 ADDITIONAL DRY RUNS RECOVERED 4 BBL FLUID. NO APPARENT FLUID ENTRY. SWIFN COSTS PREVIOUS DALLY CUMULATIVE 'Ri~a $133,315 $3,7501 $137,065, S u pervis ion $18,700 $750 $19,450 Rentals $24,350 $600 $24,950 Roustabouts $4,100 $0 $4,100 Transportation $110,100 $0 $110,100 Cement, Acid, Fracl $0 $0 Perforating, Logging $22,773 $7,653 $30,426 Subsurface Pumps $0 Rods, Scrapers $0 Tubing, Subs, SN $24,600 $0 $24,600 TAC, Packer, Repair $14,050 $3,450 $17,500 Others $16,500 $0 $16,500 Location $750 $0 $750 Misc. $13,075 $0 $13,075 El ectrical/Fu el $5,900 $0 $5,900 Water $6,360 $520 $6,880 Contingency $39,457 $1,672 $41,130 TOTAL $434,030 $18,395 $452,426 OCEAN ENERGY . sou.c s, Well: PIONEER UNIT ARCO BLT#1 Perfs: Location' SEC 22 T17N R3W Date: 10~29/99 DAILY RIG REPORT TD/PBTD' KB/GL Work Done on: 10/28/99 Others: Present Operation: BREAK DOWN ZONE 2 PERFS W/BJ SERVICES 2732-72' 4O92 100/130' 3902~08' 3913-40' Operations Planned: SWAB TEST ZONE 2 Time From To DAILY OPERATIONS 1 O/28/99 SITP 20 PSI BLED DOWN. FLAMMABLE GAS TO SURFACE ~MADE 1 SWAB RUN. NO FLUID ENTRY RU RIG PUMP FILL TBG WITH 15 BBL 2% KCL WATER ATTEMPT TO BD ZONE 2 PERFS ESTABLISH INJECTION ~ 1/8 BPM 2350 PSI UNABLE TO REACH HIGHER PRESSURES DUE TO LIMITATIONS OF PUMP' 'SWAB BACK 15 BBL FLUID. SWIFN. I I I , COSTS PREVIOUS DAILY CUMULATIVE IRi9 $137,065 $3,750 $140,815 Supervision $19,450 $750 $20,200 Rentals $24,950 $600 $25,550 Roustabouts $4,100 $0 $4,100 Transportation $110,100 $0 $110,100 Cement, Acid, Frac. $0 $0 Perforating, Logging $30,426 $0 $30,426 Subsurface Pumps $0 Rods, Scrapers $0 Tubing, Subs, SN $24,600 $0 $24,600 TAC, Packer, Repair $17,500 $0 $17,500 Others $16,500 $0 $16,500 Location $7501 $0 $750 Misc. $13,075, $0 $13,075 Electrical/Fuel $5,900. $0 $5,900 I w~t~r $6,880 $520 $7,400 Contingency $41,130 $562 $41,692 TOTAL $452,426 $6,182 $458,608 OCEAN ENERGY .ESOU.CES, INC. Well: PIONEER UNIT ARCO BLT#1 Location' SEC 22 T17N R3W Date: 10/30/99 10/29/99 SWAB BACK BREAKDOWN FLUID Work Done on: Present Operation: Perfs: TD/PBTD: KB/GL Others: DAILY RIG REPORT 4O92 100/130' 3902-08' 3913-40' 2732-72' Operations Planned: SWAB TEST ZONE 2 Time From To DAILY OPERATIONS 10~29~99 SlTP 0 PSI RU TO SWAB MADE 1 RUN W/NO FLUID RECOVERY RU BJ SERVICES BD ZONE 2 PERFS W/80 BBL 2% KCL WATER + .5% F75N SURFACTANT AND 1% U42 EDTA CHELATING AGENT. DROPPED 125 1.3 Sp. Gr BALL SEALERS. INITIAL PUMP IN @ 1/2 BPM 2500 PSI INCREASE RATE TO 4.6 BPM 3200 PSI. MODERATE BALL ACTION 3200 TO 3370 PSi W/BALLS ON PERFS FINAL INJECTION 4.6 BPM 3370 PSI. ISlP 2780 PSI 5 MIN 2230 PSi 10 MIN 1950 PSI 15 MIN 1870 PSI RD BJ RU TO FLOW BACK. BLED TO 0 PSI IN 3 MINUTES RU SWAB SWAB TO XN NIPPLE AT 2684' IN 5 RUNS MADE 1 RUN / HR FOR 3 HRS. FFL 2450' FINAL RATE .3 BPH 18.35 BBL FLUID RECOVERED FOR DAY 80 BBL TOTAL LOAD 61.65 BBL LOAD REMAINING. SWIFN COSTS PREVIOUS DAILY CUMULATIVE Rig $140,815' $3,750 $144,565 Supervision $20,200 $750 $20,950. Rentals $25,550 $600 $26,150 Roustabouts $4,100 $0 $4,100 Transportation $110,100 $3,537 $113,637 Cement, Acid, Frac. $0 $0i Perforating, Logging $30,426 $0 $30,426. Subsurface Pumps $0' !Rods, Scrapers Tubing, Subs, SN $24,600 $0 $24,600 TAC, Packer, Repair $17,500 $0 $17,500 , Others $16,500 $0 $16,500 Location $750 $0 $750. Misc. $13,075 $0 $13,075 Electrical/F u el $5,900 $0 $5,900 Water $7,400 $845 $8,245~ Contingency $41,692 $948 $42,640, TOTAL $458,608 $10,430 $469,038 OCEAN ENERGY . sou.o s.,Nc. PIONEER UNIT ARCO BLT#1 Location: SEC 22 T17N R3W Date: 10/31/99 10/30/99 SWAB BACK BREAKDOWN FLUID Work Done on: Present Operation' DALLY RIG REPORT Perfs: TD/PBTD: 4092 KB/GL 100/130' Others: 3902-08' 3913-40' 2732-72' Operations Planned' Time From To DAILY OPERATIONS 1 O/30/99 SITP 0 PSi RU TO SWAB IFL 880'. SWAB TO XN NIPPLE AT 2684' IN 5 RUNS RECOVERED 12.35 BBL FLUID MADE 1 RUN / HR FOR 6 HRS. RECOVERED 6.5 BBL ADDITIONAL FLUID FINAL FL @ 2450' FINAL RATE .3 BPH 18.85 BBL RECOVERED FOR DAY 80 BBL TOTAL LOAD 37.20 BBL TOTAL FLUID RECOVERED 42.8 BBL LOAD REMAINING SWIFN COSTS PREVIOUS DAILY CUMULATIVE Rig $144,56¢ $3,750 $148,3!5 S u p ervis ion $20,950 $750 $21,700 Rentals $26,150 $600 $26,750 Roustabouts $4,100 $0 $4,100 Transportation $113,637 $0 $113,63~ ,Cement, Acid, Frac. $0 $0 Pedorating, Logging $30,426 $0 $30,426 Subsurface Pumps $0 Rods, Scrapers $0 Tubing, Subs, SN $24,600 $0 $24,600 TAC, Packer, Repair $17,500 $0 $17,50.0 Others $16,500 $0 $16,500i Location $750 $0 $750 Misc. $13,075 $0 $13,075i Electrical/Fuel $5,900 $0 $5,900. Water $8,245 $520 $8,765 Contingency $42,640 $562 $43,202 TOTAL $469,038 $6,182 $475,220i OCEAN ENERGY RESOURCES, INC. PIONEER UNIT ARCO BLT#1 Location: SEC 22 T17N R3W Date: 11/1/99 Work Done on: 10/31/99 Present Operation: PERFORATE ZONE 3 2250'- 2300' Perfs: TD/PBTD: KB/GL Others: DAILY RIG REPORT 4O92 100/130' 3902-08' 3913-40' 2732-72' Operations Planned: SWAB TEST ZONE 3 Time From To DAILY OPERATIONS 1 O/31/99 SITP 0 PSI RU TO SWAB IFL 1980'. SWAB TO XN NIPPLE AT 2684' IN 1 RUN RECOVERED 3.3 BBL FLUID 80 BBL TOTAL LOAD 40.5 BBL LOAD RECOVERED 39.5 BBL LOAD REMAINING RELEASE PACKER SWAB FL TO 1250' POOH W/TUBING. NU BAKER ATLAS WIRELINE LUBRICATOR SWIFN COSTS PREVIOUS DAILY CUMULATIVE Rig $148,315 $2,150 $150,465 Supervision $21,700 $750 $22,450 Rentals $26,750 $600 $27,350 Roustabouts $4,100 $0 $4,100 .Transp°rtation $113,637 $0 $113,637 Cement; Acid, Frac. $0 $0 Perforating, Logging $30,426 $0 $30,426' Subsurface Pumps $0 Rods, Scrapers $0 Tubing, Subs, SN $24,600 $0 $24,600 TAC, Packer, Repair $17,500 $0 $17,500 Oth ers $16,500 $0 $16,500 Location $750 $0 $750 Misc. $13,075 $0 $13,075 Electrical/Fuel $5,900 $0 $5,900 Water $8,765 $520 $9,285 ~_Contingenc¥ $43,202 $402 $43,604 TOTAL $475,220 $4,422 $479,642 OCEAN ENERGY Well: PIONEER UNIT ARCO BLT#1 Location: SEC 22 T17N R3W Date: 11/2/99 11/1/99 SWAB AND FLOW EST ZONE 3 Work Done on: Present Operation' DALLY RIG REPORT Peris: TD/PBTD: 4092 KB/GL 100/130' Others: 3902-08' 3913-40' 2732-72' Operations Planned: 2250-2300' Time From To DAILY OPERATIONS 11/1/99 SlCP 0 PSI RU BAKER ATLAS WIRELINE IFL 1250'. PERFORATE ZONE 3 2250' TO 2300' W/4 1/2" ALPHA JET CASING GUN 5 JSPF. LIGHT BLOW AFTER FIRST GUN RUN BUILT TO 75 PSI IN 2 HRS WHILE PERFORATING. BLED DOWN CASING GAS TO SURFACE FLUID TO SURFACE IN 10 MINUTES. RD ATLAS WIRELINE. PU BAKER MODEL G RBP, 1 JT 2 7/8" TBG, RETRIEVAMATIC PACKER AND 2.205;'1D XN NIPPLE. RIH W/80 JTS TBG. SET RBP AT 2510'. SET PACKER W/70 JTS TBG AT 2188'. WELL FLOWING WHILE TRIPPING. RECOVERED 96 BBL SLIGHTLY GAS CUT WATER. RU TO SWAB. RECOVERED 18 BBL FLUID IN 3 RUNS. FLUID TO SURFACE IMMEDIATELY AFTER FINAL RUN. GAS CUT INCREASED SLIGHTLY WHILE SWABBING. 199 BBL TOTAL FLUID ENTRY AFTER PERFORATING. SWIFN. COSTS PREVIOUS DAILY CUMULATIVE Rig $150,465 $3,575 $154,040i Supervision $22,450 $750 $23,200! Rentals $27,350 $600! .$27,950~ Roustabouts $4,100 $0 $4,1 Transportation $113,637 $0 $113,637 Cement, Acid, Frac. $0 $0 Perforating, Logging $30,426 $9,745 $40,171 Subsurface Pumps $0 Rods, Scrapers $0 Tubing, Subs, SN $24,600 $0 $24,600 TAC, Packer, Repair $17,500 $0 $17,500 Others $16,500 $0 $16,500 Location $750 $0 $750 Misc. $13,075 $0 $13,075 Electrical/Fuel $5,900 $0 $5,900 Water $9,285 $520 $9,805 Contingency $43,604 $1,519 $45,123 TOTAL $479,642 $16,709 $496,351 OCEAN ENERGY Well: PIONEER UNIT ARCO BLT#1 Location: SEC 22 T17N R3W Date: 11/3/99 Work Done on: 11/2/99 Present Operation' SWAB AND FLOW EST ZONE 3 DALLY RIG REPORT Perfs: TD/PBTD: 4092 KB/GL 100/130' Others: 3902-08' 3913-40' 2732-72' Operations Planned' 2250-2300' Time From To DAILY OPERATIONS 11/2/99 :THAWED WELLHEAD AND START RIG SAFETY MEETING ICE PLUGS SITP 38O PSI BLED DOWN GAS IN 5 MINUTES FLUID TO SURFACE FLOWED TO TANK FOR 30 MINUTES RECOVERED 36 BBL WATER RU TO SWAB. SWAB TO TANK FOR 8 HRS RECOVERED 288 BBL GAS CUT FLUID IN 60 RUNS FFL 745' FINAL RATE 32 BPH.SAMPLE OF SWAB FLUID SENT TO LAB FOR ANALYSIS. SWIFN 324 BBL TOTAL FLUIID RECOVERED FOR DAY I COSTS PREVIOUS DAILY CUMULATIVE IRig $154,040 $4,585 $158,625 Supervision $23,200 $750 $23,950 Rentals $27,950 $600 $28,550 Roustabouts $4,100 $0 $4,100 Transportation $113,637 $0 $113,637 Cement, Acid, Frac. $0' $0 Perforating, Logging $40,171 $0 $40,171 Subsurface Pumps $0 Rods, Scrapers $0 Tubing, Subs, SN $24,600 $0 $24,600 TAC, Packer, Repair $17,500 $0 $17,500 Others $16,500 $0 $16,500 Location $750 $0 $750 Misc. $13,075 $0 $13,075 Electrical/Fuel $5,900 $0 $5,900 Water $9,805 $520 $10,325 Contingency $45,123 $646 $45,768 TOTAL $496,351 $7,101 $503,451 OCEAN ENERGY PIONEER UNIT ARCO BLT#1 Location: SEC 22 T17N R3W Date: 11/4/99 11/3/99 SWAB AND FLOW TEST ZONE 3 Work Done on: Present Operation: Perfs: TD/PBTD: KB/GL Others: DALLY RIG REPORT 4O92 100/130' 3902-08'3913-40' 2732-72' Operations Planned: 2250-2300' Time From To DAILY OPERATIONS 11/3/99 THAWED WELLHEAD AND START RIG SAFETY MEETING SITP 380 PSI BLED DOWN GAS IN 5 MINUTES FLUID TO SURFACE FLOWED TO TANK FOR 30 MINUTES RECOVERED 26 BBL WATER RU TO SWAB. SWAB TO TANK FOR 3 HRS RECOVERED 108 BBL GAS CUT FLUID IN 20 RUNS SAND LINE CROWN SHEVE BEARINGS FAILED. RU PUMP EQUIPMENT BEGIN INJECTIVITY TEST PUMPED 225 BBL WATER IN 4 HRS AT 1/2 TO 3/4 BPM 750 TO 900 PSI. SWIFN. I ! ,, COSTS PREVIOUS DAILY CUMULATIVE tRiq $158,625. $3,745 $162,370 ~ u~a erv i s ion $23,950. $750 $24,700 Rentals $28,550 $600 $29,150 Roustabouts $4,100i $0 $4,100 Transportation $113,637 $0 $113,637 Cement, Acid, Frac. $0 $0 Perforating, Logging $40,171 $0 $40,171 Subsurface Pumps $0 Rods, Scrapers $0 Tubing, Subs, SN $24,600 $0 $24,600 TAC, Packer, Repair $17,500 $0 $17,500 I Others $16,500 $0 $16,500 Location $750 $0 $750 Misc. $13,075 $0 $13,075 El ectrical/F u el $5,900 $0 $5,900 Water $10,325 $675 $11,000 [Contin~lency $45,768 $577 $46,345 TOTAL $503,451 $6,347 $509,798 OCEAN ENERGY Well: Location: PIONEER UNIT ARCO BLT#1 Perfs: SEC 22 T17N R3W TD/PBTD: 1115199 KB/GL 11/4/99 Others: Date: Work Done on' Present Operation: PERFORATE ZONE 4 2086'-2100' DALLY RIG REPORT 4O92 100/130' 3902-08' 3913-40' 2732-72' Operations Planned: RUN PACKER AND TEST ZONE 4 2250-2300' Time From To DAILY OPERATIONS 11 ~4~99 THAWED WELLHEAD AND START RIG SAFETY MEETING SlTP 380 PSI PUMPED BREAKDOWN AND INJECTION TEST ON ZONE 3 PUMPED 455 BBL PRODUCED WATER AT 1 BPM PRESSURE VARIED FROM 1400 PSI TO 1900 PSI ISlP 1450 15 MIN 1045 SWIFN. COSTS PREVIOUS DAILY CUMULATIVE 'Rig $162,370 $4,155 $166,525j Supervision $24,700 $750 $25,450 Rentals $29,150 $600 $29,750 Roustabouts $4,100 $0 $4,100 Transportation $113,637 $0 $113,637 Cement, Acid, Frac. $0 $0 Perforating, Logging $40,171 $0 $40,171 Subsurface Pumps $0 Rods, Scrapers $0 Tubing, Subs, SN $24,600 $0 $24,600 TAC, Packer, Repair $17,500 $0 $17,500 Others $16,500 $0 $16,500 Location $750 $0 $750 Misc. $13,075 $0 $13,075 Electrical/Fu el $5,900 $0 $5,900 Water $11,000 $850 $11,850 Contingency $46,345 $636 $46,981 TOTAL $509,798 $6,991 $516,789 OCEAN ENERGY RESOURCES, INC. PIONEER UNIT ARCO BLT#1 Location: SEC 22 T17N R3W Date' 11/6/99 Work Done on: 11/5/99 Present Operation' RUN WIRELINE SET PACKER DAILY RIG REPORT Perfs: TD/PBTD: 4092 KB/GL 100/130' Others: 3902-08' 3913-40' 2732-72' Operations Planned' TEST ZONE 4 2250-2300' 2086'-2100' Time From To DALLY OPERATIONS 11/5/99 'THAWED WELLHEAD AND START RIG SAFETY MEETING ~SITP 380 PSI BLED DOWN TBG RELEASE PACKER PU 10 JTS TBG RETRIEVE RBP RESET RBP AT 2196' TEST RBP TO 500 PSI POOH W/TBG LD PACKER RU BAKER ATLAS WIRELINE PERFORATE ZONE 4 IN 2 RUNS. 2086' - 2100' 5 JSPF 4 1/2" ALPHA JET CASING GUN SICP 380 PSI 5 MINUTES AFTER PERFORATING RD BAKER ATLAS SWIFN MONITOR PRESSURES OVERNIGHT. COSTS PREVIOUS DAILY CUMULATIVE !Rig $166,525 $3,950, $170,475 Supervision $25,450 $750 $26,200 Rentals $29,750 $600 $30,350 Roustabouts $4,100 $0 $4,100 Transportation $113,637 $0 $113,637 Cement, Acid, Frac. $0 $0 Perforating, Logging $40,171 $3,063 $43,234 Subsurface Pumps $0 Rods, Scrapers $0 Tubing, Subs, SN $24,600 $0 $24,600 TAC, Packer, Repair $17,500 $0 $17,500, Others $16,500 $0 $16,500 Location $750 $0 $750 Misc. $13,075 $0 $13,075 Electrical/Fuel $5,900 $0 $5,900 Water $11,850 $520 $12,370 Contingency $46,981 $888 $47,869 TOTAL $516,789 $9,771 $526,560 OCEAN ENERGY Well: PIONEER UNIT ARCO BLT#1 Location: SEC 22 T17N R3W Date: 11/7/99 Work Done on' 11/6/99 Present Operation: RUN PACKER SEAL ASSEMBLY Perfs: TD/PBTD: KB/GL Others: DALLY RIG REPORT 4092 100/130' 3902-08'3913-40' 2732-72' Operations Planned: TEST ZONE 4 2250-2300' 2086'-2100' Time From To DAILY OPERATIONS 11/6/99 SICP 38O PSI RU BAKER ATLAS WIRELINE RIH W/8.5" GUAGE RING TAG RBP AT 2196' PU BAKER OIL TOOLS 9 5/8" SCl PACKER W/2.205" ID XN NIPPLE W/HALLIBURTON XXN PLUG IN PLACE. SET PACKER AT 2035'. RD BAKER ATLAS BLED DOWN CASING IN 1 MINUTE. SWIFN MONITOR PRESSURES OVERNIGHT. COSTS PREVIOUS DAILY CUMULATIVE .Rig $170,475; $3,950 $174,425 Supervision $26,200, $750 $26,950 Rentals $30,350 $600 $30,950 Roustabouts $4,100 $0 $4,100 Transportatic~n $113,637 $0 $113,637 Cement, Acid, Frac. $0 $0 Perforating, Loggin~l $43,234 $3,674 $46,908 Subsurface Pumps $0 ~.~ods, Scrapers $0 .Tubing, Subs, SN $24,600 $0 $24,600 TAC, Packer, Repair $17,500 $27,450 $44,950 Others $16,500 $0 $16,500 Location $750 $0 $750 Misc. $13,075 $0 $13,075 Electrical/Fuel $5,900 $0 $5,900 Water $12,370 $520 $12,890 Contin ~en c¥ $47,869 $3,694 $51,564 TOTAL $526,560 $40,638 $567,199 OCEAN ENERGY Well: PIONEER UNIT ARCO BLT#1 Location: SEC 22 T17N R3W Date: 11/8/99 Work Done on: 11/7/99 Present Operation: SWAB TEST ZONE 4 Perfs: TD/PBTD: KB/GL Others: DAILY RIG REPORT 4O92 100/130' 3902-08' 3913-40' 2732-72' Operations Planned: TEST ZONE 4 2250-2300' 2086'-2100' Time From To DAILY OPERATIONS 11/7/99 SICP 0 PSI PU BAKER OIL TOOLS SC1 SEAL ASSEMBLY TIH W/65 JTS TBG !SPACE OUT AND LAND TUBING IN SC1 PACKER AT 2035'. RU POLLARD WIRELINE SLICKLINE UNIT RETRIEVE EQUALIZER INSERT. PRESSURE EQUALIZE TO 380 PSI IN 2 MINUTES RETRIEVE XXN PLUG FROM XN NIPPLE RD POLLARD WIRELINE RU TO SWAB. BLED TBG TO 0 PSI IN 5 MINUTES FLOWING 1" STREAM SWAB TO PACKER IN 14 RUNS FFL 1500' FINAL RATE 18 BPH RECOVERED 51 BBL IN 2 HRS. SWIFN COSTS PREVIOUS DAILY CUMULATIVE Rig $174,425. $3,950 $178,375J Supervision $26,950 $750 $27,700 Rentals $30,950 $600 $31,550 Roustabouts $4,100 $0 $4,100 Transportation $113,637 $0 $113,637 Cement, Acid, Frac. $0 $0 Perforating, Logging $46,908 $2,890 $49,798 Subsurface Pumps $0 Rods, Scrapers $0 Tubing, Su.bs, SN $24,600 $0 $24,600 TAC, Packer, Repair $44,950 $3,400 $48,350 Others $16,500 $0 $16,500 Location $750 $0 $750 Misc. $13,075 $0 $13,075 Electrical/Fuel $5,900 $0 $5,900 Water $12,370 $520 $12,890 Contingency $51,512 $1,211 $52,723 TOTAL $566,627 $13,321 $579,948 OCEAN ENERGY RESOURCES, INC. DAILY RIG REPORT Well: Location: Date: Work Done on: Present Operation: Operations Planned: PIONEER UNIT ARCO BLT#1 SEC 22 T17N R3W 11/9/99 1/8/99 SWAB TEST ZONE 4 Perfs: TD/PBTD: KB/GL Others: 4O92 100/130' 3902-08' 3913-40' 2732-72' TEST ZONE 4 2250-2300' 2086'-2100' Time From To DAILY OPERATIONS 11/8/99 SITP 38O PSI BLED DOWN TUBING WATER TO SURFACE NO GAS RU TO SWAB -' SWAB TO XN NIPPLE IN 12 RUNS RECOVERED 44 BBL WATER W/NO GAS MADE 5 RUNS/HR FOR 7 HRS AVG RATE 26 BPH AVG FL 1000' 100% WATER NO GAS 226 BBL TOTAL FLUID RECOVERED FOR DAY FFL 1000' FINAL RATE 27 BPH SWIFN COSTS PREVIOUS DAILY CUMULATIVE $4,115 $182,490 :Supervision $27,700 $750 $28,450 Rentals $31,550 $600 $32,150 Roustabouts $4,100 $0 $4,100 Transportation $113,637 $0 $113,637 Cement, Acid, Frac. $0 $0 .Perforating, Logging $49,798 $0 $49,798 i Subsurface Pumps $0 Rods, Scrapers $0 Tubing, Subs, SN $24,600 $0 $24,600 TAC, Packer, Repair $48,350 $0 $48,350 Others $16,500 $0 $16,500 Location $750 $0 $750 Misc. $13,075 $0 $13,075 El ect rical/F u el $5,900 $0 $5,900 Water $12,890 $520, $13,410 Contingency $52,723 $599 $53,321 TOTAL $579,948 $6,584 $586,531 OCEAN ENERGY RESOURCES, INC. PIONEER UNIT ARCO BLT#1 Location: SEC 22 T17N R3W Date: 11/1 O/99 11/9/99 SWAB TEST 7ONE 4 Work Done on: Present Operation: Perfs: TD/PBTD: KB/GL Others: DAILY RIG REPORT 4O92 100/130' 3902-08' 3913-40' 2732-72' Operations Planned: TEST ZONE 4 2250-2300' 2086'-2100' Time From To DAILY OPERATIONS 11/9/99 SITP 380 PSI BLED DOWN TUBING FLARED GAS FOR 30 SECONDS FOLLOWED BY WATER RU TO SWAB SWAB TO XN NIPPLE IN 12 RUNS RECOVERED 44 BBL WATER W/NO GAS MADE 5 RUNS/HR FOR 5 HRS AVG RATE 26 BPH AVG FL 1000' 100% WATER NO GAS FLUID ENTRY BEGAN FALLING OFF SHARPLY IN FINAL 2 HOURS FINAL FL 1500' FINAL RATE 13 BPH. RECOVERED 203 BBL FLUID FOR DAY SWIFN COSTS PREVIOUS DAILY CUMULATIVE i_Rig $182,490 $4,115 $186,605 uuperwsion $28,450 $750 $29,200 Re'ntais $32,150 $600 $32,750 : Rou stabouts $4,100 $0 $4,100 Transportation $113,637 $0 $113,637 Cement, Acid, Frac. SO $0 Perforating, Logging $49,798 $0 $49,798 Subsurface Pumps $0 Rods, Scrapers $0 Tubing, Subs, SN $24,600 S0 $24,6001 TAC, Packer, Repair $48,350 $0 $48,350 Others $16,500 $0 $16,500 Location $750 $0 $750 Misc. $13,075 $0~ $13,075 Electrical/Fuel $5,9001 $0 $5,900 Water $13,410 $520 $13,930 Contingency $53,321 $599 $53,920 TOTAL $586,531 $6,584 $593,115 OCEAN ENERGY . sou.c s..NCm Well: PIONEER UNIT ARCO BLT#1 Location: SEC 22 T17N R3W Date: 1/11/09 Work Done on: 11/10/09 Present Operation: SWAB TEST ZONE 4 Perfs: TD/PBTD: KB/GL Others: DallY RIG REPORT 4O92 100/130' 3902-08' 3913-40' 2732-72' Operations Planned: TEST ZONE 4 2250-2300' 2086'-2100' Time From To DAILY OPERATIONS 11/10/99 SITP 380 PSI BLED DOWN TUBING FLARED GAS FOR 30 SECONDS FOLLOWED BY WATER RU TO SWAB SWAB TO XN NIPPLE IN 12 RUNS RECOVERED 44 BBL WATER SLIGHTLY GAS CUT MADE 5 RUNS/HR FOR 5 HRS AVG RATE 20 BPH AVG FL 1000' 100% WATER SLIGHTLY GAS CUT RECOVERED 144 BBL FLUID FOR THE DAY SWIFN COSTS PREVIOUS DAILY CUMULATIVE Rig $186,605 $3,070 $189,675 Supervision $29,200 $750 $29,950; Rentals $32,750 $600 $33,350 Roustabouts $4,100 $0 $4,100i Transportation $113,637 $0 $113,637 Cement, Acid, Frac. $0 $0 Perforating, Logging $49,798 $0 $49,798 Subsurface Pumps $0 Rods, Scrapers $0 Tubing, Subs, SN $24,600 $0 $24,600 TAC, Packer, Repair $48,350 $0 $48,350 Others $16,500 $0 $16,500 Location $750, $0 $750 Misc. $13,075 $0 $13,075 Electrical/Fuel $5,900 $0 $5,900 Water $13,410 $520 $13,930 Contingency $53,868 $494 $54,362 TOTAL $592,543 $5,434, $597,977 OCEAN ENERGY .ESOU.C S.,.c. PIONEER UNIT ARCO BLT#1 Location' SEC 22 T17N R3W Date: 11/12~00 Work Done on: 11/11/99 Present Operation' RDMO CH&P RIG 19 DALLY RIG REPORT Perfs: TD/PBTD: 4092 KB/GL 100/130' Others: 3902-08' 3913-40' 2732-72' Operations Planned' SI WAIT ON CASING PATCH 2250-2300' 2086'-2100' Time From To DAILY OPERATIONS 11/11/99 ..- SlTP 380 PSI BLED DOWN TUBING FLARED GAS FOR 30 SECONDS FOLLOWED BY WATER RU POLLARD WIRELINE SLICKLINE EQUIPMENT SET XXP PLUG AND PRONG IN XN NIPPLE AT 2044' ~STING OUT OF SC1 PACKER I LD 4 JTS TBG. LAND TUBING AT 1920' KB. ND BOPE NU WELLHEAD. SWI LS TUBING FROM DERRICK. PREP TO MOVE RIG. ,,, ., COSTS PREVIOUS DAILY CUMULATIVE -15,i9 $189,675 $3,750 $193,425 _Supervision $29,950 $750 $30,70'0 Rentals $33,350 $600 $33,950 Roustabouts $4,100 $0 $4,100 '.Transportation $113,637 $0 $113,637 Cement, Acid, Frac. $0 $0 ~erforatin9, Logging $49,798 $2,862 $52,660 Subsurface Pumps $0 Rods, Scrapers $0 _Tubing, Subs, SN $24,600 $0 $24,600 !TAC, Packer, Repair $48,350 $0 $48,350 i Others $16,500 $0 $16,500 l Location $750 $0 $750 TVI is c. $13,075 $0 $13,075 -Electrical/Fuel $5,900 $0 $5,900 ~v'ater $13,930 $520 $14,45.0 ,.Contingency $54,362 $848 $55,210, TOTAL $597,977 $9,330 $607,307_ OCEAN ENERGY DAILY RIG REPORT Well: Location: Date: Work Done on: Present Operation: Operations Planned: PIONEER UNIT ARCO BLT#1 SEC 22 T17N R3W 12/15/99 12/14/99 RETRIEVE SC1 PACKER ~ 2035' PREP TO SET CASING PATCH 2245-2305' Perfs: TD/PBTD: KB/GL Others: 4O92 100/130' 3902-08'3913-40' 2732-72' 2250-2300' 2086'-2100' Time From To DAILY OPERATIONS 12/13~99 MIRU CHP RIG 19 AND RELATED EQUIPMENT 12/14~99 ND WELLHEAD NU BOPE PU 5 JTS TBG AND STING INTO SC1 PACKER AT 2035' RU POLLARD WIRELINE TO RETRIEVE XXP PLUG IN XN NIPPLE AT 2044' UNABLE TO RETRIEVE PRONG FROM XXP PLUG RD WIRELINE EQUIPMENT POOH W/TUBING LD SEAL ASSEMBLY SWIFN COSTS PREVIOUS DAILY CUMULATIVE IF~i9 $193,425 $7,880 $201,305 S u p ervision $30,700 $1,500 $32,200 Rentals $33,950 $400 $34,350 Roustabouts $4,100 $0 $4,100 Transportation $113,637 $4,890 $118,527 Cement, Acid, Frac. $0 $0 Perforating, Logging $52,660 $4,789 $57,449 Subsurface Pumps $0 Rods, Scrapers $0 Tubing, Subs, SN $24,600 $0 $24,600 TAC, Packer,. Repair $48,350 $0 $48,350 Others $16,500 $0 $16,500 Location $750 $0 $750 Misc. $13,075 $0 $13,075 El ectrical/Fu e'l $5,900 $0 $5,900, Water $14,450 $1,040 $15,490 !Contingency $55,210 $2,050 $57,260 TOTAL $607,307 $22,549 $629,856 OCEAN ENERGY PIONEER UNIT ARCO BLT#1 Location: SEC 22 T17N R3W Date: 12/16/99 12/15/99 RETRIEVE RBP AT 2196' Work Done on: Present Operation: Perfs: TD/PBTD: KB/GL Others: DALLY RIG REPORT 4O92 100/13O' 3902-08' 3913-40' 2732-72' Operations Planned: PREP TO SET CASING PATCH 2245-2305' 2250-2300' 2086'-2100' Time From To DAILY OPERATIONS 12/15199 SICP 0 PSI PU BAKER SCl RETRIEVING TOOL AND RIH ENGAGE SCl PACKER AT 2035' RELEASE PACKER ANNULUS BEGAN FLOWING IMMEDIATELY POOH W/TBG. LD PACKER AND RETRIEVING TOOL PU BAKER MODEL G RETRIEVING HEAD AND RIH W/65 JTS TBG. SWlFN COSTS PREVIOUS DAILY CUMULATIVE Rig $201,305 $3,775 $205,080. Supervision $32,200 $750 $32,950 Rentals $34,350 $400 $34,750 Roustabouts $4,100 $1,380 $5,480 Transportation $118,527 $1,145 $119,672 ,Cement, Acid, Frac. $0 $0 Perforating, Logging $57,499 $0 $57,499 Subsurface Pumps $0 Rods, Scrapers $0 Tubing, Subs, SN $24,600 $0 $24,600 TAC, Packer, Repair $48,350 $2,250 $50,600 Others $16,500: $0 $16,500 Location $750 $0 $750 Misc. $13,075 $0 $13,075. Electrical/Fuel $5,900 $0 $5,900' Water $15,490 $1,350 $16,840 Contingency $57,265 $1,1051 $58,370 TOTAL $629,911 $12,155 $642,066 OCEAN ENERGY Well: PIONEER UNIT ARCO BLT#1 Location' SEC 22 T17N R3W Date: 12/17/99 Work Done on: 12/16/99 Present Operation: RETRIEVE RBP FROM MODEL D DAILY RIG REPORT Perfs: TD/PBTD: 4092 GL/KB 100/130' Others: 3902-08' 3913-40' 2732-72' Operations Planned' PREP TO SET CASING PATCH 2245-2305' 2250-2300' 2086'-2100' Time From To DAILY OPERATIONS 12/16/99 SICP 400 PSI LOCAL TEMP. -26F BD CSG PU RETRIEVING TOOLS TIH W/2 7/8" J 55 TBG TO 2196' ENGAGE MODEL G RBP ANNULAR FLOW INCREASED NOTICABLY AS RBP RELEASED POOH W/TBG ANNULUS FLOWING HARD TO 500' FROM SURFACE. TBG BEGAN FLOWING GAS CUT WATER 1-2 BPM. ATTEMPT TO KILL TBG W/FRESH WATER. NO NOTICABLE DECREASE IN TBG. FLOW. POOH W/WET STRING LOCAL TEMP -10F. MODEL G RBP WAS NOT RECOVERED. RIH W/RETRIEVING HEAD. 'ENGAGED RBP (~ 2196'. PU 8 JTS TBG. FOLLOWING RBP DOWNHOLE. !SET AND RELEASED RBP AT 2504' KB. POOH W/TBG. LD RBP/SWIFN. RECOVERED 378 BBL WATER IN 14 HRS WHILE TRIPPING FOR DAY. SWIFN LOCALTEMP -14F. COSTS PREVIOUS DAILY CUMULATIVE Rig $205,080 $5,485 $210,565 Supervision $32,950 $750~ $33,700 Rentals $34,750 $980 $35,730 Roustabouts $4,100 $970 $5,070~ Transportation $119,672 $0 $119,672 Cement, Acid, Frac. $0, $3,770 $3,770 Perforating, Logging $57,499 $0 $57,499 Subsurface Pumps $0 Rods, Scrapers $0 Tubing, Subs, SN $24,600 $0 $24,600 TAC, Packer, Repair $50,600 $1,977 $52,577 Others $16,500 $0 $16,500 Location $750i $0 $750 Misc. $13,075 $0 $13,075 Electrical/Fuel $5,900~ $0. $5,900 Water $16,840 $1,970 $18,810 Contingency $58,232 $1,590 $59,822 TOTAL $640,548 $17,492 $658,040 OCEAN ENERGY PIONEER UNIT ARCO BLT#1 Location: SEC 22 T17N R3W Date: 12/18/99 Work Done on: 12/17/99 Present Operation: RETRIEVE RBP FROM MODEL D Perfs: TD/PBTD: GL/KB Others: DAILY RIG REPORT 4O92 100/130' 3902-08' 3913-40' 2732-72' Operations Planned: PREP TO SET CASING PATCH 2245-2305' 2250-2300' 2086'-2100' Time From To DAILY OPERATIONS 12/17/99 SICP 400 PSI LOCAL TEMP. -12F BD CSG PU RETRIEVING TOOLS TIH W/2 7/8" J 55 TBG TO 3510' TBG FLOWING WHILE TRIPPING TUBING AIR SLIPS BROKE MAIN PIN SWIFN REPAIR SLIPS AT MACHINE SHOP COSTS PREVIOUS DAILY CUMULATIVE iRig $210,565 $2,970 $213,535 Sup e rvisio n $33,700 $750 $34,450 Rentals $35,730! $675 $36,405 Roustabouts $5,070 $970 $6,040 Transportation $119,672 $0 $119,672 Cement, Acid, Frac. $3,770 $0 $3,770 Perforating, Logging $57,499 $0 $57,499 Subsurface Pumps $0 Rods, Scrapers $0 Tubing, Subs, SN $24,600 $0 $24,600 TAC, Packer, Repair $52,557 $1,977 $54,534 Others $16,500 $0 $16,500: Location $750 $0 $750 Misc. $13,075 $0 $13,075 Electrical/Fuel $5,900 $0 $5,900 Water $18,810 $1,260 $20,070 Contingency $59,820 $860 $60,680 TOTAL $658,018 $9,462 $667,480 OCEAN ENERGY RESOURCES, INC. Well: PIONEER UNIT ARCO BLT#1 Location: SEC 22 T17N R3W Date: 12/19/99 Work Done on' 12/18/99 Present Operation: RUN CASING SCRAPER AND STRING MILL DAILY RIG REPORT Perfs: TD/PBTD: 4092 GL/KB 100/130' Others: 3902-08' 3913-40' 2732-72' Operations Planned: PREP TO SET CASING PATCH 2245-2305' 225O-23OO' 2086'-2100' Time From To DAILY OPERATIONS 12/18/99 SICP 400 PSI LOCAL TEMP. -2F WAIT ON TUBING SLIP REPAIRS BD TUBING AND CASING PU 10 JTS TBG. TAG FILL AT 3828'. WASH DOWN AND ENGAGE F PLUG ASSEMBLY IN MODEL D @ 3840' RELEASE PLUG ASSEMBLY. POOH W/TBG. LD 50 JTS TBG. STAND BACK REMAINING TUBING. LD TOOLS SWIFN. COSTS PREVIOUS DAILY CUMULATIVE Rig $213,535 $3,750 $217,285 Supervision $34,4501 $750 $35,200 Rentals $36,405 $675 $37,080 Roustabouts $6,040 $970 $7,010 Transportation $119,672 $0 $119,672 Cement, Acid, Frac. $3,770 $0 $3,770 Perforating, Logging $57,499 $0 $57,499 Subsurface Pumps $0 Rods, Scrapers $0 Tubing, Subs, SN $24,600 $0 $24,600 TAC, Packer, Repair $5,434 $1,977i $7,411 Others $16,500 $0 $16,500 Location $750 $0 $750 Misc. $13,075 $0 $13,075 Electrical/Fuel $5,900 $0 $5,900 Water $20,070. $1,877 $21,947, Contingency $55,770 $1,000 $56,770 TOTAL $613,470 $10,999 $624,469 OCEAN ENERGY RESOURCES, INC. PIONEER UNIT ARCO BLT#1 Location: SEC 22 T17N R3W Date: 12/20/99 Work Done on: 12/19/99 Present Operation: RUN RBP TO 1000' SWI FOR HOLIDAY Perfs: TD/PBTD: GL/KB Others: DAILY RIG REPORT 4092 100/130' 3902-08' 3913-40' 2732-72' Operations Planned: PREP TO SET CASING PATCH 2245-2305' 2250-2300' 2086'-2100' Time From To DAILY OPERATIONS 12/19/99 SICP 400 PSI LOCAL TEMP. 20F PU 8 1/2" BIT CASING BRUSH,CASING SCRAPER, 8.525 STRING MILL ANS XO'S. TIH W/74 JTS TBG. WORK TOOLS THRU PERFS AT 2100' AND 2300'. MINIMAL TIGHT ARES FROM 2090 TO 2100' AND 2285' RU BJ SERVICES CIRCULATE WELLBORE WITH 200 BBL PRODUCED WATER POOH W/TBG. LD 40 JTS AND STAND BACK REMAINING TBG. LD TOOLS. SWIFN I COSTS PREVIOUS DAILY CUMULATIVE Rig $217,285 $4,170 $221,455 Supervision $35,200 $750 $35,950 Rentals $37,080 $675 $37,755i Roustabouts $7,010 $970 $7,980 Transportation $119,672 $0 $119,672 Cement, Acid, Frac. $3,770 $2,273i $6,043 Perforating, Logging $57,499 $0 $57,499 Subsurface Pumps $0 Rods, Scrapers $17,970 $17,970 Tubing, Subs, SN $24,600: $0 $24,600 TAC, Packer, Repair $7,411 $0 $7,411 Others $16,500 $0 $16,500 Location $750 $0 $750 Misc. $13,075 $0 $13,075 , Electrical/Fuel $5,900 $0 $5,900 Water $21,947 $970 $22,917 Contingency $56,770 $2,778 $59,548 TOTAL $624,469 $30,556 $655,025 OCEAN ENERGY RESOURCES, INC. PIONEER UNIT ARCO BLT#1 Location: SEC 22 T17N R3W Date: 12/21/99 Work Done on: 12//20/99 Present Operation' SI FOR HOLIDAYS Perfs: TD/PBTD: GL/KB Others: DAILY RIG REPORT 4O92 100/130' 3902-08'3913-40' 2732-72' Operations Planned' PREP TO SET CASING PATCH 2245-2305' 2250-2300' 2086'-2100' Time From To DAILY OPERATIONS 12/20/99 SICP 400 PSI LOCAL TEMP. 20F PU BAKER 9 5/8" MODEL G RBP AND TIH W/34 JTS TBG SET RBP AT 1074' KB LD 5 JTS TBG. SWI. ISD UNTIL 1/04/2000 24 HOUR SECURITY ON LOCATION COSTS PREVIOUS DAILY CUMULATIVE Rig $221,455 $2,250 $223,705 Supervision $35,950 $1,500 $37,450 Rentals $37,755 $675 $38,430: Roustabouts $7,980 $460 $8,440i Transportation $119,672 $0 $119,672 Cement, Acid, Frac. $6,043 $0 $6,043 Perforating, Logging $57,499 $0 $57,499 Subsurface Pumps $0 Rods, Scrapers $17,979 $0 $17,979 Tubing, Subs, SN $24,600: $0 $24,600 TAC, Packer, Repair $7,411 $3,500 $10,911 Others $16,500 $0 $16,500 Location $750 $0 $750 Misc. $13,075 $0 $13,075 Electrical/Fuel $5,900 $0 $5,900 Water $22,917 $1,880 $24,797 Contingenc¥ $59,549 $1,027 $60,575 TOTAL $655,035 $11,292 $666,326 OCEAN ENERGY RESOURCES, INC. Well: PIONEER UNIT ARCO BLT#1 Location: SEC 22 T17N R3W Date: 1/5/00 Work Done on: 1/4/00 Present Operation: RUN CASING PATCH 2245' - 2305' Perfs: TD/PBTD: GL/KB Others: DALLY RIG REPORT 4O92 100/130' 3902-08' 3913-40' 2732-72' Operations Planned: 2250-2300' 2086'-2100' Time From To DAILY OPERATIONS 1/4/OO SICP 100 PSI LOCAL TEMP. 20F THAW WELLHEAD AND BD CASING PU 5 JTS TBG RETRIEVE RBP LAY DOWN TUBING PREP TO RUN CSG PATCH. SWIFN COSTS PREVIOUS DAILY CUMULATIVE Rig $223,705 $3,880 $227,585 Supervision $37,450 $1,500 $38,950. Rentals $38,430 $675 $39,105i Roustabouts $8,440 $460 $8,900 Transportation $119,672 $0 $119,672 Cement, Acid, Frac. $6,043 $0 $6,043 Perforating, Logging $57,499i $0 $57,499 Subsurface Pumps $0 Rods, Scrapers $17,979 $0 $17,979 Tubing, Subs, SN $24,600 $0 $24,600 TAC, Packer, Repair $7,411 $0 $7,411 Others $16,500 $0 $16,500 Location $750 $0 $750 Misc. $13,075 $0 $13,075 Electrical/Fuel $5,900 $0 $5,900 Water $24,979 $940 $25,919 Contingency $60,243 $746 $60,989 TOTAL $662,676 $8,201 $670,877 OCEAN ENERGY Well: PIONEER UNIT ARCO BLT#1 Location: SEC 22 T17N R3W Date: 1/6/99 Work Done on: 1/5/99 Present Operation: LD CASING PATCH TOOLS Perfs: TD/PBTD: GL/KB Others: DALLY RIG REPORT 4O92 100/130' 3902-08' 3913-40' 2732-72' Operations Planned: RUN PKR & RBP. PERFORM LEAKOFF TEST 2250-2300' 2086'-2100' Time From To DAILY OPERATIONS 1/5/99 .. SlCP 400 PSI LOCAL TEMP. -16F PU WEATHERFORD CASING PATCH AND SETTING TOOLS RIH W/70 JTS TBG. RU BJ SERVICES SEAT CASING PATCH FROM 2245' TO 2305' KB. ~ 750 PSI. .. PULL THROUGH PATCH AT 26,000# OVER STRING WEIGHT POOH W/15 JTS TBG. -, SWIFN. .. ,--, COSTS PREVIOUS DALLY CUMULATIVE Rig $227,585 $3,775 $231,360 Supervision $38,950 $750 $39,700 Rentals $39,105 $675 $39,780 Roustabouts $8,900 $1,280 $10,180 Transportation $119,672 $0 $119,672 Cement, Acid, Frac. $6,043 $2,740 $8,783 Perforating, Logging $57,499 $0 $57,499 Subsurface Pumps $0 Rods, Scrapers $17,979 $0 $17,979 Tubing, Subs, SN $24,600 $0 $24,600 TAC, Packer, P, epair $7,411 $0 $7,411 Others $16,500 $17,200 $33,700 Location $7501 $0 $750 Misc. $13,075 i $0 $13,075_ Electrical/Fuel $5,900 $0 $5,90.0.. Water $25,919 $940 $26,859.. !Contingency $60,989 $2,736 $63,725_ TOTAL $670,877i $30,096 $700,973 OCEAN ENERGY Well: PIONEER UNIT ARCO BLT#1 Location: SEC 22 T17N R3W Date: 1/7/00 Work Done on: 1/6/00 Present Operation: PUMP IN AND LEAK OFF TEST 2086-2100' Perfs: TD/PBTD: GL/KB Others: DALLY RIG REPORT 4O92 100/130' 3902-08' 3913-40' 2732-72' Operations Planned: 2250-2300' 2086'-2100' Time From To DAILY OPERATIONS 1/6/00 SICP 400 PSI LOCAL TEMP. 6F POOH W/TUBING. LD AND LOAD OUT WEATHERFORD CASING PATCH TOOLS PU BAKER MODEL G RBP AND RETRIEVAMATIC PACKER TIH W/68 JTS TBG SET RBP AT 2153'. LD 3 JTS TBG. SET PACKER AT 2037' SWIFN. COSTS PREVIOUS DAILY CUMULATIVE Rig $231,360 $3,140 $234,500 Supervision $39,700 $750 $40,450 Rentals $39,780 $675 $40,455 Roustabouts $10,180 $450 $10,630 Transportation $119,672 $0 $119,672 Cement, Acid, Frac. $8,783 $2,740 $11,523 Perforating, Loggin9 $57,499 $0 $57,499 Subsurface Pumps $0 Rods, Scrapers $17,979 $0 $17,979~ Tubing, Subs, SN $24,600 $0 $24,600, TAC, Packer, Repair $7,411 $3,450 $10,861 Others $33,700 $13,600 $47,300 Location $750: $0 $750 Misc. $13,075 $0 $13,075 El ectrical/F u el $5,900i $0 $5,900 Water $26,859 $520 $27,379 Contingency $63,725 $2,533 $66,257 TOTAL $700,973 $27,858 $728,830 OCEAN ENERGY PIONEER UNIT ARCO BLT#1 Perfs: Location: SEC 22 T17N R3W TD/PBTD: GL/KB Others: Date: 1/8/00 Work Done on: 1/7/00 Present Operation: RETRIEVE PRESSURE RECORDERS SWAB TEST DAILY RIG REPORT 4O92 100/130' 3902-08' 3913-40' 2732-72' Operations Planned: 2250-2300' 2086'-2100' Time From To DAILY OPERATIONS 1/7/00 SlCP 0 PSI LOCAL TEMP. 10F :RU POLLARD WIRELINE RIH AND SET TANDEM ELECTRONIC PRESSURE RECORDERS IN XN NIPPLE AT 2037'. RU BJ SERVICES FILL HOLE AND PRESSURE TO 1000 PSI. UNABLE TO PUMP INTP PERFS SURGE PRESSURES 2 TIMES PUMPED +/- 1.5 BBL INTO PERFS REPRESSURE TBG TO 1200 PSI ANNULUS TO 1000 PSI SI TO RECORD LEAKOFF COSTS PREVIOUS DAILY CUMULATIVE Rig $234,500 $3,780 $238,280 Supervision $40,450 $750 $41,200 Rentals $40,455 $675 $41,130 Roustabouts $10,630 $01 $10,630 Transportation $119,672 $0 $119,672 Cement, Acid, Frac. $11,523 $3,661 $15,184 Perforating, Logging $57,499 $3,784 $61,283 Subsurface Pumps $0 Rods, Scrapers $17,979 $0 $17,979 Tubing, Subs, SN $24,600 $0 $24,600 TAC, Packer, Repair $10,861 $0 $10,861 Oth ers $47,300 $0 $47,300 Location $750 $0 $750 Misc. $13,075 $0 $13,075 Electrical/Fuel $5,900; $0 $5,900 Water $27,379 $520 $27,899 Contingency $66,257 $1,317 $67,574 TOTAL $728,830 $14,487 $743,317 OCEAN ENERGY Well: PIONEER UNIT ARCO BLT#1 Location: SEC 22 T17N R3W Date: 1/9/00 Work Done on: 108/00 Present Operation: SWAB TEST 2086-2100' Perfs: TD/PBTD: GL/KB Others: DALLY RIG REPORT 4O92 100/130' 3902-08' 3913-40' 2732-72' Operations Planned: 2250-2300' 2086'-2100' Time From To DALLY OPERATIONS 1/8/99 SITP/CP 275/400 PSI LOCAL TEMP. 10F RU POLLARD WIRELINE BLED TBG TO 0 PSI RETRIEVE PRESSURE RECORDERS FROM XN NIPPLE ~ 2037'. DOWNLOAD DATA AND FORWARD DISC TO DENVER RU SWAB EQUIPMENT SWAB TO XNNIPPLE AT 2037' IN 4 RUNS RECOVERED 15 BBL FLUID WAIT 1 HOUR AND MADE 1 ADDITIONAL RUN W/NO RECOVERY. SWIFN SITP/CP 0/275 PSI COSTS PREVIOUS DAILY CUMULATIVE Rig $238,280 $3,780 $242,060 Supervision $41,200 $750 $41,950 Rentals $41,130 $675 $41,805 'Roustabouts $10,630 $0 $10,630 Transportation $119,672 $0 $119,672 Cement, Acid, Frac. $15,184 $0 $15,184 Perforating, Logging $61,283 $4,890 $66,173 Subsurface Pumps $0 Rods, Scrapers $17,979 $0 $17,979 Tubing, Subs, SN $24,600; $0 $24,600i TAC, Packer, Repair $10,861 $0 $10,861 Others $47,300 $0 $47,300 Location $750 $0 $750 Misc. $13,075 $0 $13,075 Electrical/Fuel $5,900 $01 $5,900 Water $27,899 $920 $28,819 Contingency $67,574 $1,102 $68,676 TOTAL $743,317 $12,117 $755,434 OCEAN ENERGY DAILY RIG REPORT Well: PIONEER UNIT ARCO BLT#1 Perfs: Location: SEC 22 T17N R3W TD/PBTD: Date: 1/10/00 GL/KB Work Done on: 1/10/00 Others: Present Operation: SWAB TEST 2086-2100' 4O92 100/130' 3902-08'3913-40' 2732-72' Operations Planned: 2250-2300' 2086'-2100' Time From To DAILY OPERATIONS 1/9/OO SITP/CP 20/0 PSI LOCAL TEMP. -10F BD TBG. GAS TO SURFACE RU TO SWAB. IFL 1850' 200' FLUID ENTRY RECOVERED 1 BBL WATER WAIT 1 HOUR AND MADE 1 ADDITIONAL RUN W/NO RECOVERY. SWIFN COSTS PREVIOUS DAILY CUMULATIVE Rig $242,060 $1,275 $243,335 Supervision $41,950 $750 $42,700 Rentals $41,805 $675 $42,480 ! Roustabouts $10,630 $0 $10,630 Transportation $119,672 $0 $119,672 Cement, Acid, Frac. $15,184 $0i $15,184 Perforating, Logging $66,173 $0 $66,173 Subsurface Pumps $0 Rods, Scrapers $17,979 $0 $17,979 Tubing, Subs, SN $24,600 $0 $24,6001 TAC, Packer, Repair $10,861 $0 $10,861 Others $47,300 $0 $47,300 Location $750, $0 $750 Misc. $13,075 $0 $13,075 Electrical/Fuel $5,900 $0 $5,900 Water $28,819 $520 $29,339 . Contingency $68,676 $322 $68,998 TOTAL $755,434 $3,542 $758,976 OCEAN ENERGY DAILY RIG REPORT Well: PIONEER UNIT ARCO BLT#1 Perfs: Location: SEC 22 T17N R3W TD/PBTD: Date: 1/11/00 GL/KB Work Done on: 1/10/00 Others: Present Operation: SI WAIT ON LOGGING EQUIPMENT 4O92 100/13O' 3902-08' 3913-40' 2732-72' Operations Planned: REPERFORATE ZONE 2086-2100' 2250-2300' 2086'-2100' Time From To DAILY OPERATIONS 1/10/00 SlTP/CP 20/0 PSI LOCAL TEMP. -10F BD TBG. GAS TO SURFACE RU TO SWAB. IFL 1850' 200' FLUID ENTRY RECOVERED 1 BBL WATER WAIT 1 HOUR AND MADE 1 ADDITIONAL RUN W/NO RECOVERY. SWI WAIT FOR LOGGING EQUIPMENT BEING TRANSPORTED FROM NORTH SLOPE. COSTS PREVIOUS DAILY CUMULATIVE Rig $243,335 $1,275 $244,610' Supervision $42,700 $750 $43,450 Rentals $42,480 $420 $42,900 Roustabouts $10,630 $0 $10,630 Transpor[ation $119,672 $0 $119,672 Cement, Acid, Frac. $15,184 $0 $15,184 Perforating, Logging $66,173 $0 $66,173 Subsurface Pumps $0 Rods, Scrapers $17,979 $0 $17,979 Tubing, Subs, SN $24,600 $0 $24,600 TAC, Packer, ,Repair $10,861 $0 $10,861 Oth ers $47,300 $0 $47,300 Location $750 $0 $750 Misc. $13,075 $0 $13,075 Electrical/Fuel $5,900 $0 $5,900 Water $29,339 $520 $29,859 Contingency $68,998 $297 $69,294 TOTAL $758,976 $3,262 $762,237 .Curtis, .L (Larry) From: ed cooper [ecooper@vcn.com] Sent: Wednesday, January 12, 2000 1:01 AM To: CHUCK POLLARD; CHUCK WILSON; DOUG WALTON; LARRY CURTIS; LORETTA MURPHY; AUDRA MOONEY; BRET JAMESON; BRYAN SAUNDERS; JEAN CHARTRAND; KlM HOLTZ Subject: MORNING REPORT BLT #1 1/12/00 BLT #1 SI WAIT FOR PERF TRUCK FROM NORTH SLOPE 1/12/00 OCEAN ENERGY Well: PIONEER UNIT ARCO BLT#1 Location: SEC 22 T17N R3W Date: 1/13/00 Work Done on: 1/12/00 Present Operation: SI WAIT ON LOGGING EQUIPMENT Perfs: TD/PBTD: GL/KB Others: DAILY RIG REPORT 4O92 100/130' 3902-08' 3913-40' 2732-72' Operations Planned: REPERFORATE ZONE 2086-2100' 2250-2300' 2086'-2100' Time From To DALLY OPERATIONS 1/12/00 SlTP/CP 20/0 PSI LOCAL TEMP. -18F SI WAIT ON PERFORATING TRUCK ENROUTE FROM NORTH SLOPE COSTS PREVIOUS DALLY CUMULATIVE F'~ig $245,885 $1,275 $247,160 Supervision $44,200 $750 $44,950 Rentals $43,320 $420 $43,740 Roustabouts $10,630! $0 $10,630 T. ransportation $119,6721 $0 $119,672 Cement, Acid, Frac. $15,184 $0 $15,184 Perforating, Logging $66,173 $0 $66,173 Subsurface Pumps $0 Rods, Scrapers $17,979 $0 $17,979 Tubing, Subs, SN $24,600 $0 $24,600 .T. AC, Packer, Repair $10,861 $0 $10,861 Others $47,300 $0 $47,300 Location $750 $0 $750 Misc. $13,075 $0 $13,0751 Electrical/Fuel $5,900 $0 $5,900 Water $29,859 $0 $29,859 Contingency $69,539 $245 $69,783 TOTAL $764,927 $2,690 $767,616 OCEAN ENERGY Well: PIONEER UNIT ARCO BLT#1 Location: SEC 22 T17N R3W Date: 1/14/00 Work Done on: 1/13/00 Present Operation' SI WAIT ON LOGGING EQUIPMENT Perfs: TD/PBTD: GL/KB Others: DALLY RIG REPORT 4092 100/130' 3902-08' 3913-40' 2732-72' Operations Planned: REPERFORATE ZONE 2086-2100' 2250-2300' 2086'-2100' Time From To DALLY OPERATIONS 1/13/OO SITP/CP 20/0 PSI LOCAL TEMP. -24F SI WAIT ON PERFORATING TRUCK ENROUTE FROM NORTH SLOPE COSTS PREVIOUS DAILY CUMULATIVE Rig $247,160 $1,275 $248,435 Supervision $44,950 $750 $45,700 Rentals $43,740 $420 $44,160 Roustabouts $10,630 $0 $10,630 Transportation $119,672 $0 $119,672 Cement, Acid, Frac. $15,184 $0 $15,184 Perforating, Logging $66,173 $0 $66,173 Subsurface Pumps $0 Rods, Scrapers $17,979 $0 $17,979 Tubing, Subs, SN $24,600 $0 $24,600 TAC, Packer, Repair $10,861 $0 $10,861 Others $47,300 $0 $47,3001 Location $750 $0 $7501 Misc. $13,075 $0 $13,0751 Electrical/Fuel $5,900 $0 $5,900 Water $29,859 $0 $29,859 Contingency $69,783 $245 $70,028 TOTAL $767,616 $2,690 $770,306 OCEAN ENERGY PIONEER UNIT ARCO BLT#1 Location: SEC 22 T17N R3W Date: 1/15/00 Work Done on: 1/14/00 Present Operation: REPERFORATE ZONE 2086-2100' Perfs: TD/PBTD: GL/KB Others: DAILY RIG REPORT 4O92 100/130' 3902-08' 3913-40' 2732-72' Operations Planned: SWAB TEST 2086-2100 2250-2300' 2086'-2100' Time From To DAILY OPERATIONS 1/14/00 SlTP/CP 20/0 PSI LOCAL TEMP. -14F BD TBG RELEASE PACKER SWAB FL TO 700' POOH W/TBG. LD PACKER NU BAKER ATLAS LUBRICATOR. SWINF WAIT ON PERF TRUCK. COSTS PREVIOUS DAILY CUMULATIVE Rig $248,435 $2,880 $251,315 Supervision $45,700 $750 $46,450 Rentals $44,160 $420 $44,580 Roustabouts $10,630, $0 $10,630 Transportation $119,6721 $0 $119,672 Cement, Acid, Frac. $15,184 $0 $15,184 Perforating, Logging $66,173 $0 $66,173 Subsurface Pumps $0 Rods, Scrapers $17,979 $0 $17,979 Tubing, Subs, SN $24,600 $0 $24,600 TAC, Packer, Repair $10,861 $0 $10,861 Others $47,300 $0 $47,300 Location $750 $0 $750 i Misc. $13,075 $0 $13,075 Electrical/Fuel $5,900 $0 $5,900 Water $29,859 $520 $30,379 Contingency $70,028 $457 $70,485 TOTAL $770,306 $5,027 $775,333 OCEAN ENERGY PIONEER UNIT ARCO BLT#1 Location' SEC 22 T17N R3W Date: 1/16/00 Work Done on: 1/15/00 Present Operation: REPERFORATE ZONE 2086-2100' DAILY RIG REPORT Perfs: TD/PBTD: 4092 GL/KB 100/130' Others: 3902-08' 3913-40' 2732-72' Operations Planned: SWAB TEST 2086-2100 2250-2300' 2086'-2100' , , Time From To DAILY OPERATIONS 1/15/O0 SITP/CP 20/0 PSI LOCAL TEMP. -18F SI WAIT ON BAKER ATLAS ENGINEER TO BE FLOWNIN FROM NORTH SLOPE. WEATHER CONDITIONS GROUNDING ALL PLANES COSTS PREVIOUS DALLY CUMULATIVE Rig $251,315 $1,270 $252,585 Supervision $46,450 $750 $47,200 Rentals $44,580 $420 $45,000 Roustabouts $10,630 $0 $10,630 T. ransportation $119,672 $0 $119,672 Cement, Acid, Frac. $15,184 $0 $'~5,184 Perforating, Logging $66,173 $0 $66,173 Subsurface Pumps $0 Rods, Scrapers $17,979 $0 $17,979 Tubing, Subs, SN $24,600 $0 $24,600 TAC, Packer, Repair $10,861 $0 $10,861 Others $47,300 $0 $47,300' Location $750] $0 $750 Misc. $13,0751 $0 $13:075 I Electrical/Fuel $5,9001 $0 $5,900 Water $30,379 $520 $30,899 ;Contingency $70,485 $296' $70,781 TOTAL $775,333 $3,256 $778,589 · , OCEAN ENERGY RESOURCES, INC. Well: PIONEER UNIT ARCO BLT#1 Location: SEC 22 T17N R3W Date: 1/17/00 Work Done on: 1/16/00 Present Operation: SWAB TEST 2086-2100 DAILY RIG REPORT Perfs: TD/PBTD: 4092 GL/KB 100/130' Others: 3902-08' 3913-40' 2732-72' Operations Planned: 2250~2300' 2086'-2100' Time From To DAILY OPERATIONS 1/16/00 SlTP/CP 20~0 PSI LOCAL TEMP. -28F UNLOAD AND RU BAKER ATLAS WlRELINE EQUIPMENT DELIV'ERED FRON NORTH SLOPE. TAG RBP @ 2134' C'ORRELATE TO OPEN HOLE LOGS REPERFORATE COAL ZONE AT 2086'-2100' 5 JSPF 4 1/2" ULTRA JET CASING GUN FL (~ 740' LIGHT BLOW AT SURFACE AFTER PERFORATING. RD WIRELINE EQUIPMENT. PU BAKER RETRIEVAMATIC PACKER. TIH W 65 JTS 2/8 EUE TBG. SET PACKER AT 2046' W.14,000# COMPRESSION. WINTERIZE AND SWIFN. LOCAL TEMP -21F. ,, COSTS PREVIOUS DAILY CUMULATIVE Rig ' $252,585 $4,387 $256,972 Supervision $47,200 $750 $47,950~ Rentals $45,000 $420 $45,4201 Roustabouts $10,630 $0 $10,6301 Transportation $119,672 $0 $119,6721 Cement, Acid, Frac. $15,184 $0 $15,18~l Perforating, Logging $66,173 $18,487 $84,660] Subsurface Pumps $01 Rods, Scrapers $17,979 $0 $17,9791 Tubing, Subs, SN $24,600 $0 $24,600 TAC, Packer, Repair' $10,861 $0 $10,861 Others $47,300 $0 $47,300 Location $750 $0 $750 , Misc. $13,075 $0 $13,075 Electrical/Fuel ¢5,900 $0 $5,900 Water $30,899 $520 $31,419 i Contingenc¥ $70,781 $2,456 $73,23.7 TOTAL $778,589 $27,020 $805,609 OCEAN ENERGY RESOURCES, INC. PIONEER UNIT ARCO BLT#1 Location: SEC 22 T17N R3W Date: 1/18/00 Work Done on: 1/17/00 Present Operation: SWAB TEST 2086-2100 Perfs: TD/PBTD: GL/KB Others: DALLY RIG REPORT 4092 100/130' 3902-08' 3913-40' 2732-72' Operations Planned' BREAK DOWN PERFS 2086-2100' 2250-2300' 2086'-2100' Time From To DAILY OPERATIONS 1/1'7/00 SITP/CP 20/0 PSI LOCAL TEMP. -18F RU SWAB EQUIPMEN'i' IFL 700' SWAB TO XN NIPPLE AT 2036' IN 3 RUNS .RECOVERED 8 BBL FLUID MADE 1 RUN/HR FOR 4 HRS W/NO ADDITIONAL RECOVERY SWI WAiT FOR BD EQUIPMENT. L., I i [. COSTS PREVIOUS DAILY CUMULATIVE Rig $256,972 $2,120 $259,092 .Supervision $47,950 $750 $48,700 Rentals $45,420 $420 . $45,840 'Roustabouts $10,630 $0 $10,630 Transportation $119,672 $0 $119,672 Cement, Acid, Frac. $15,184 $0 $15,184 Perforating, Logging $84,660 $0 $84,660 Subsurface Pumps $0 .R. 0.ds, Scrapers $17,979 $0~ $17,97.9 Tubing,. Subs, SN $24,600 $01 $24,600 TAC, Packer, Repair $10,861 $01 $10,861 Others $47,300 $01 $47,300 Location $750 $0 $750 , . Misc. $13,075 $0 $13,075 Electrical/Fuel $5,900 $0 $5,9oo Water $31,419 $520 $31,939_ Contingency $73,237 $381 $73,618: TOTAL $805,609 $4,191 $809,800' OCEAN ENERGY .ESOU.CES,,NC. Well: PIONEER UNIT ARCO BLT#1 Location: SEC 22 T17N R3W Date: 1/19/00 Work Done on: 1/18/00 Present Operation: SWAB TEST 2086-2100 DALLY RIG REPORT Perfs: TD/PBTD: 4092 GL/KB 100/130' Others: 3902-08' 3913-40' 2732-72' Operations Planned: PUMP IN LEAKOFF TEST 2250-2300' 2086'-2100' Time From To DAILY OPERATIONS 111810'O SITP/CP 20~0 PSI LOCAL TEMP. 8F RU SWAB EQUIPMENT IFL 1700' 300' FLUID ENTRY OVERNIGHT SWAB TO XN NIPPLE AT 2036' IN 3 RUNS RECOVERED 2 BBL FLUID RU BJ SERVICES PUMP EQUIPMENT · , FILL ANNULUS AND PRESSURE TO 500 PSI. FILL TBG W/12 BBL 2% KCL WATER ESTABLISH INJECTION AT 1/4 BPM 1830 PSI INCREASE RATE TO 1 BPM 2120 PSI INCREASE RATI'- TO 2 BPM 2230 PSi INCREASE RATE TO 4 BPM 2330 PSI BACKSIDE pRESSURE INCREASED TO 1100 PSI SD BLED ANNULUS TO 700 PSI. · . :SURGE BACK TBG PRESSURE 2 TIMES CONTINUE INJECTION AT 2 BPM 2230 PSI. ANNULUS PRESSURED TO 1200 PSI. INJECTED A TOTAL OF 31 BBL 2% KCL WATER DOWN TBG. ~ ISIP 1810 PSI 15MIN 1290 PSI. [ BD TBG AND ANNULUS i TBG FLOWED BACK 1 BBL FLUID RU TO SWAB SWAB TO XN NIPPLE AT 2036' IN 4 RUNS , . RECOVERED 15 BBL FLUID ,. - MADE 1 RUN/HR FOR 3 HRS W/NO FLUID RECOVERY. SDFN LEFT WELL OPEN TO TANK. RECOVERED 16 OF 31 BBL LOAD COSTS PREVIOUS DAILY CUMULATIVE .Rig $259,092 $3,940 $263,0'3~2i Supervision $48,700 $750 $49,45b Rentals $45,840 $420 $46,260 Roustabouts $10,630 $0 $10,630 , . Transportation $119,672 $0 $119,672. Cement, Acid, Frac. $15,184 $2,845 $18,029 Perforating, Logging $84,660 $0 $84,660 ;Subsurface Pumps $~ Rods, Scrapers $17,979' $0 $17,979 Tubing, Subs, SN $24,600' $0 $24,600. TAC, Packer, Repair $10,861 $0 $10,861 Others $47,3001 $0 $47,300. Location $750i $0 $750 Misc. $13,0751 $0 $13,075 Electrical/Fuel $5,9oo $0 $5,9OO Water $31,939 $520 $32,459 Contingency $73,618 $848 $74,466 TOTAL $809,800 $9,323, $819,123_ OCEAN ENERGY Well: Location: PIONEER UNIT ARCO BLT#1 Perfs: SEC 22 T17N R3W TD/PBTD: 1/20/00 G L/KB 1/19/00 Others: PUMP IN LEAKOFF TEST Date: Work Done on: Present Operation: DAILY RIG REPORT 4O92 100/13O' 3902-08' 3913-40' 2732-72' Operations Planned: RECORD PRESSURES 225O-230O' 2086'-2100' I Tir~e From To DAILY OPERATIONS .. 1/19/OO .., ,. SlTP/CP 20/0 PSI LOCAL TEMP. 18F ,. . RU SWAB EQUIPMENT IFL 1600' 400' FLUID ENTRY OVERNIGHT SWAB TO XN NIPPLE AT 2036' IN 3 RUNS RECOVERED 2 BBL FLUID - MADE 1 RUN/2 HRS FOR 6 HRS W/NO FLUID RECOVERY. . SWIFN . , . . .. ,-- , . , . COSTS PREVIOUS DAILY CUMULATIVE Rig $263,032! $3,180 $266,212 .Supervision $49,450 $750 $50,200 Rentals $46,260 $420 $46,680 'Roustabouts $10,630 $0 $10,630 '.?rans portation $119,672 $0 $119,672 Cement, Acid, Frac. $18,029 $0 $18,029 Perforating, Logging $84,660 $0 $84,660 Subsurface Pumps $0 _Rods, Scrapers $17,979 $0 $17,979 T. ubin9, Subs, SN $24,600 $0. $':~4,600 .TAC, Paci.~er, .Repair $10,861 $0 $10,861 Others $47,300 $0, $47,300 Location $750 $0 $750 ~lisc. $13,075 $0 $13,075 Electrical/Fuel $5,900 $0 $5,900 Water $32,459 $520, $32,979 LContingenc¥ $74,466 $487 $74,953 TOTAL $819,123 $5,357 $824,480 OCEAN ENERGY RESOURCES, INC. Well: Location: Date: DALLY RIG REPORT PIONEER UNIT ARCO BLT#1 Peris: SEC 22 T17N R3W TD/PBTD: 4092 1/21/00 GL/KB 100/130' Work Done on: 1/20/00 Others: 3902-08' 3913-40' Present Operation: RETRIEVE PRESSURE RECORDERS 2732-72' Operations Planned: RETRIEVE PKR AND RBP 2250-2300' 2086'-2100' Time From To DALLY OPERATIONS 1/20/00 SITP/CP 20/0 PSI LOCAL TEMP. 18F RU SWAB EQUIPMENT IFL 1600' 300' FLUID ENTRY OVERNIGHT SWAB TO XN NIPPLE AT 2036' IN 2 RUNS RECOVERED 2 BBL FLUID RU POLLARD WIRELINE SLICKLINE EQUIPMENT SET 1 ELECTRONIC PRESSURE RECORDER IN XN NIPPLE @ 2036' RU BJ SERVICES PUMP TRUCK FILL TBG W/10 BBL 2 % KCL WATER INJECT INTO ZONE 2086-2100' ~ 1/4 BPM 1670 TO 1830 PSI 0 PSI ON ANNULUS PUMPED 30 BBL INTO FORMATION. SD ISlP 1675 PSI SI FOR 24 HOURS , , COSTS PREVIOUS DAILY CUMULATIVE Rig $266,212 $3,180 $269,392, Supervision $50,200 $750 $50,9.5_01 Rentals $46,680 $420 $47,100 Roustabouts $10,630' $0 $10,63~ Transportation $119,6721 $0 $119,672 Cement, Acid, Frac. $1.8,029 $2,880 $20,909 Perforating, Logging $84,660 $2,775 $87,43~ sb Subsurface Pumps , Rods, Scrapers $17,979 $0 '$17,979 Tubing, Subs, SN $24,600 $0 $24,600 TAC, Packer, Repair $10,861 $0 $1.0,861 Others $47,300 $0 $47,300 Location $750 $0 $750 Misc. $13,075 $0 $13,075. Electrical/Fuel $5,900 $0 $5,900 Water $32,979 $520 $33,499 Contingency $74,953 $1,053 $76,005_ TOTAL $824,480 $11,578 $836,057 OCEAN ENERGY Well PIONEER UNIT ARCO BLT#1 Location: Perfs: SEC 22 T17N R3W TD/PBTD: 1/22/00 GL/KB 1/21/00 Others: Date: Work Done on: Present Operation: RETRIEVE PKR AND RBP DALLY RIG REPORT 4O92 100/130' 3902-08' 3913-40' 2732-72' Operations Planned: SWAB TEST ALL ZONES 2250-2300' 2086'-2100' Time From To DAILY OPERATIONS 1/21/00 SITP/CP 540~720 PSI LOCAL TEMP. 22F ANNULUS PRESSURED UP OVERNIGHT BD TBG AND ANNULUS RU POLLARD WIRELINE SLICKLINE EQUIPMENT RETRIEVE PRESSURE RECORDER FROM XN NIPPLE AT 2036' READ PRESSURES AND FORWARD DISC TO DENVER RU TO SWAB SWAB TO XN NIPPLE RECOVERED 12 BBL MADE 1 ADDITIONAL RUN W/NO RECOVERY SWIFN. COSTS PREVIOUS DAILY CUMULATIVE Rig $269,392 $3,180 $272,572 Supervision $50,950 $750 $51,700 Rentals $47,100 $420 $47,520 i Roustabouts $10,630 $0 $10,630! Transportation $119,672 $0 $119,672! Cement, Acid, Frac. $20,909 $2,880 $23,789 Perforating, Logging $87,435 $2,650 $90,085 Subsurface Pumps $0 Rods, Scrapers $17,979 $0 $17,979 Tubing, Subs, SN $24,600 $0 $24,600 TAC, Packer, Repair $10,861 $0 $10,861 Others $47,300 $0 $47,300 Location $750 $0 $750 Misc. $13,075 $0 $13,075 Electrical/Fuel $5,900 $0 $5,900 Water $33,499 $520 $34,019 Contingency $76,0051 $1,040; $77,045 TOTAL $836,0571 $11,440! $847,497 OCEAN ENERGY RESOURCES, INC. Well: PIONEER UNIT ARCO BLT#1 Location' SEC 22 T17N R3W Date: 1/23/00 Work Done on: 1/22/00 Present Operation: ATTEMPT TO RETRIEVE RBP Perfs: TD/PBTD: GL/KB Others: DAILY RIG REPORT 4O92 100/130' 3902-08' 3913-40' 2732-72' Operations Planned' 2250-2300' 2086'-2100' Time From To DAILY OPERATIONS 1/22/00 SITP/CP 0/0 PSI LOCAL TEMP. 22F RU TO SWAB IFL 1700' 300' FLUID ENTRY. SWAB TO XN NIPPLE ~ 2036' RECOVERED 2 BBL RELEASE PACKER PU 3 JTS TBG. ENGAGE AND RELEASE RBP AT 2150' PULLED 50' TBG AND PULLED TIGHT TO 40,000# ATTEMPT TO RELEASE RBP AT 2099'. RELEASE PACKER FROM RBP AND POOH W/TBG. LD PACKER SWIFN. I COSTS PREVIOUS DAILY CUMULATIVE I Rig $272,572 $3,180 $275,752 · · Supervision $51,700 $750 $52,450i Rentals $47,520 $420 $47,940 Roustabouts $10,630 $0 $10,630 Transportation $119,672 $0 $119,672 Cement, Acid, Frac. $23,7891 $0i $23,789 Perforating, Logging $90,085 $0 $90,085 Subsurface Pumps $0 Rods, Scrapers $17,979 $0 $17,979 Tubing, Subs, SN $24,600 $0 $24,600 TAC, Packer, Repair $10,861 $1,845 $12,706 Others $47,300 $0 $47,300 Location $750 $0 $750 Misc. $13,075 $0 $13,075 El e ctrical/F u el $5,900 $0 $5,900 Water $34,019 $520 $34,539 Contingency $77,045 $672 $77,717 TOTAL $847,497 $7,387 $854,884 OCEAN ENERGY Well: PIONEER UNIT ARCO BLT#1 Location: SEC 22 T17N R3W Date: 1/24/00 Work Done on: 1/23/00 Present Operation' ATTEMPT TO RETRIEVE RBP Perfs: TD/PBTD: GL/KB Others: DallY RIG REPORT 4092 100/130' 3902-08'3913-40' 2732-72' Operations Planned' 2250-2300' 2086'-2100' Time From To DAILY OPERATIONS 1/23/00 SITP/CP 0/0 PSI LOCAL TEMP. 28F PU RETRIEVING HEAD AND BUMPER SUB. TIH W/TBG ENGAGE RBP AT 2099' ATTEMPT TO RELEASE RBP AT 2099'. IMMEDIATE TORQUE W/MINIMAL UPSTRAIN ON TBG. ATTEMPT TO BEAT RBP FREE DOWNWARD UNABLE TO WORK RBP FREE. RELEASE FROM RBP W/TBG AND POOH SWIFN. COSTS PREVIOUS DAILY CUMULATIVE !Rig $275,752 $2,338 $278,090 Supervision $52,450 $750 $53,200 Rentals $47,940 $420 $48,360 Roustabouts $10,630 $0 $10,630 Transportation $119,672 $0i $119,672 Cement, Acid, Frac. $23,789 $0 $23,789 Perforating, Logging $90,085 $0 $90,085 Subsurface Pumps $0 Rods, Scrapers $17,979 $0 $17,9791 Tubin9, Subs, SN $24,600 $0 $24,600 TAC, Packer, Repair $12,706 $2,110 $14,816 Others $47,300 $0 $47,300 Location $750 $0 $750 Misc. $13,075 $0 $13,075 Electrical/Fuel $5,900 $0 $5,900 Water $34,539 $520 $35,059 Contingenc¥ $77,7171 $614 $78,331 TOTAL $854,884 $6,752 $861,636 OCEAN ENERGY PIONEER UNIT ARCO BLT#1 Location: SEC 22 T17N R3W Date: 1/25/00 Work Done on' 1/24/00 Present Operation: RETRIEVE RBP Perfs: TD/PBTD: GL/KB Others: DAILY RIG REPORT 4092 100/130' 3902-08' 3913-40' 2732-72' Operations Planned: SWAB TEST ALL ZONES 2250-2300' 2086'o2100' Time From To DAILY OPERATIONS 1/24/00 SlCP 200 PSI LOCAL TEMP. 28F BD CASING 1/2" FLOW PR RETRIEVING HEAD, BUMPER SUB, 4 6" DC'S AND RIH W/TBG. ENGAGE RBP AT 2099' WORK RBP FREE DOWNWARD RESET RBP AT 2160'. RELEASE FROM RBP AND POOH W/TBG. PU 8.525" STRINGMILL IN BHA BETWEEN RH AND BUMPER SUB. RIH W/TBG. RU POWER SWIVEL WORK STRINGMILL THRU PERFS 2086-2100' ENGAGE AND RELEASE RBP AT 2160' POOH WORK RBP THRU PERFS. POOH W/10 JTS TBG. SWIFN COSTS PREVIOUS DALLY CUMULATIVE Rig $278,090 $3,875 $281,965 Supervision $53,200 $750 $53,950 Rentals $48,360 $755 $49,115 Roustabouts $10,630 $0 $10,630 Transportation $119,672 $0 $119,672 Cement, Acid, Frac. $23,789 $0 $23,789 Perforating, Logging $90,085 $0 $90,085 Subsurface Pumps $0 Rods, Scrapers $17,979 $0 $17,979 Tubin~], Subs, SN $24,600 $0 $24,600; TAC, Packer, Repair $14,816 $1,880 $16,696 Others $47,300 $0i $47,3001 Location $750 $0 $750 Misc. $13,075 $01 $13,075 Electrical/Fuel $5,900 $0 $5,900 Water $35,059 $520 $35,579 I Contingency $78,331 $778 $79,109 TOTAL $861,636 $8,558 $870,194 OCEAN ENERGY Well: PIONEER UNIT ARCO BLT#1 Location: SEC 22 T17N R3W Date: 1/25/00 Work Done on: 1/25/00 Present Operation: SWAB TEST CASING PATCH 2245-2305' Perfs: TD/PBTD: GL/KB Others: DALLY RIG REPORT 4O92 100/130' 3902-08'3913-40' 2732-72' Operations Planned: 2250-2300' 2086'-2100' Time From To DALLY OPERATIONS 1/25/00 SlCP 200 PSI LOCAL TEMP. 28F POOH W/TBG. LD DC'S AND STRING MILL LD RBP AND RETRIEVING HEAD PU BAKER RETRIEVAMATIC PACKER AND RIH W/68 JTS TBG SET PKR AT 2160' RU TO SWAB. IFL AT SURFACE FLOWING LIGHTLY SWAB TO TANK FOR 2 1/2 HRS RECOVERED 78 BBL LIGHTLY GAS CUT FLUID. I - 3% SOLIDS IN SWAB SAMPLES. FFL STABILIZED AT 600' 35 BPH. SWIFN. COSTS PREVIOUS DAILY CUMULATIVE I Rig $281,965 $3,145 $285,110 !Supervision $53,950 $750 $54,700 Rentals $49,115 $520 $49,635 Roustabouts $10,630 $0 $10,630 Transportation $119,672 $0 $119,672 Cement, Acid, Frac. $23,789 $0 $23,789 Perforating, Logging $90,085 $0 $90,085 Subsurface Pumps $0i Rods, Scrapers $17,979 $0 $17,979, Tubing, Subs, SN $24,600 $0 $24,600 TAC, Packer, Repair $16,696 $950 $17,646 Others $47,300 $0 $47,300 Location $750; $0 $750 Misc. $13,075 $0 $13,075 Electrical/Fuel $5,900 $0 $5,900 Water $35,579 $1,190 $36,769 Contingency $79,109 $656i $79,764 TOTAL $870,194 $7,211 $877,404 OCEAN ENERGY DAILY RIG REPORT Well: Location: Date: Work Done on: Present Operation: Operations Planned: PIONEER UNIT ARCO BLT#1 SEC 22 T17N R3W 1/27/00 1/26/00 RUN RBP FOR TEMPORARY SHUT IN Perfs: TD/PBTD: GL/KB Others: 4O92 100/130' 3902-08'3913-40' 2732-72' RDMO SERVICE UNIT 2250-2300' - ¢¢,~¢. i .... ~-: ,~';.~'-~ 2086'-2100' Time From To DAILY OPERATIONS 1/26/00 SICP 400 PSI LOCAL TEMP. 28F BD TUBING. FLOWED 65 BBL WATER IN 1 1/2 HRS RELEASE PACKER RU TO SWAB SWAB TO TANK FOR 2 1/2 HRS RECOVERED 98 BBL LIGHTLY GAS CUT FLUID. FFL STABILIZED AT 400' 40 BPH. LIGHT BLOW ON ANNULUS POOH W/TBG. SWIFN. COSTS PREVIOUS DAILY CUMULATIVE Rig $285,110' $3,145 $288,255 Supervision $54,700 $750. $55,450 Rentals $49,635 $520' $50,155 !Roustabouts $10,630 $0 $10,630 Transportation $119,672 $0 $119,672 Cement, Acid, Frac. $23,789 $0 $23,789 Perforating, Logging $90,085~ $0 $90,085 Subsurface Pumps $0 Rods, Scrapers $17,979 $0 $17,979 Tubing, Subs, SN $24,600 $0 $24,600 TAC, Packer, Repair $17,646 $0 $17,646 Others $47,300 $0 $47,300 Location $750 $0 $750 Misc. $13,075 $0 $13,075 Electrical/Fuel $5,900 $0 $5,900 Water $36,769 $780 $37,549i I :Conbngenc¥ $79,764 $520 $80,284 TOTAL $877,404 $5,715 $883,119 ARCO BLT #1 Status Until Sprin~l of 2000 NFNW Section 22: Township 17 North- Ran§e 3 West IVlatanuska-Susitna Borough, Alaska 12 '- 10 11 Flapper Valve Well Detail/Casing Detail Conductor: 20"/94# H-40 / Welded @ 321'. Cemented with 1314 sx. Surface: 13-3/8" / 68# / L-80 / BTC @ 1700'. Cemented with 1400 sx, Production: 9-5/8"/47# / L-80 / BTC @ 4,494'. Cemented with 1117 sx. Liner: 7"/29# / L-80 from 4324'-6200'. Cemented with 470 sx. TD: 6,200'. PBTD: 4,092' Tubing: 2-7/8" / 6.5# / ]-55 / EUE 8rd @ 1,073'. RBP set @ 1104', Production Perforations: 2086' - 2100', 2732' - 2772'. 10. HOWCO Patch 2245'- 2305'. Sealed peris: 2250'-2300'. 11. 12. Packer @ +-3840' with flapper value in place. Injection Perforations: 3902' - 3908' and 3913' - 3940'. 1-27-00 Circulated a diesel freeze blanket into the 9 5/8" x 2 7/8" tubing annulus and into the 2 7/8" tubing. Shut-in and secured the wellhead. The ARCO BLT #1 well and location will be monitored on a regular basis while shut-in to ensure safety, security, and well control. TONY KNOWLE$, GOVERNOR ALAS~ OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 August 16. 1999 Scott Webb Regulatory. Coordinator Ocean Energy, Inc. 1670 Broadway Suite 2800 Denver. CO 80202-4826 Re; Pioneer Unit BLT 1 Ocean Energy, Inc. Permit No: 99-068 Sur Loc: 793'FNL, 1333'FWL, SEC. 22. T17N, R03W, SM Btmhole Loc. 793'FNL, 1333'FWL, SEC. 22, T17N, R03W, SM Dear Mr. Webb: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required bv law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice max' be given bv contacting the Commission at 279-1433. ~~Sinc/~--~ ," Robert N. Christcnson? P.E. Chairman BY ORDER OF THE COMMISSION dlf/Enclosures CC; Department of Fish & Game. Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage Alaska 99501-3192 Re: THE APPLICATIONS OF OCEAN ) ENERGY RESOURCES, INC. for an ) exception to spacing requirements of ) 20 AAC 25.055(a)(2) and the notice ) provisions of 20 AAC 25.055(b) to ) allow re-entry and testing ofthe BLT #1 ) exploratory gas well. ) Conservation Order No. 448 Ocean Energy Resources, Inc. BLT #1 Exploratory Gas Well August 11, 1999 IT APPEARING THAT: Union Oil Company of Califomia ("Unocal") submitted applications dated July 13, 1999, requesting a spacing exception to 20 AAC 25.055(a)(2) and a variance from the public notice provisions of 20 AAC 25.055(b) to allow re-entry and testing of the BLT #1 exploratory gas well. . Ocean Energy Resource, Inc. ("Ocean Energy") assumed operatorship of the Pioneer Unit, including the BLT #1 well, from Unocal prior to expiration of the protest period. 3. The Commission published notice of an opportunity for hearing in the Anchorage Daily News and the Frontiersman on July 20, 1999, pursuant to 20 AAC 25.540. 4. The Commission did not receive any protest to the application. FINDINGS': Ocean Energy proposes to reenter and test the BLT #1, which is located 1334 feet from the west line, 795 feet from the north line in Section 22, T17N, R3W, Seward Meridian. 2. Ocean Energy and Unocal are the owners of State of Alaska lease ADL 374124, which includes Section 22, T17N, R3W, S.M. ge The BLT #1 well .was previously drilled by ARCO Alaska, Inc. in 1992 under the authority of Permit to Drill 91-130 and Conservation Order 280. CO 280 granted the original spacing exception for the well on November 21, 1991. Conservation Order 4'~ Page 2 August 11, 1999 4. Ocean Energy plans to evaluate the well for gas, but does not plan to commercially produce the well at this time. o The public notice provisions of 20 AAC 25.055(b) require notification by registered mail of all owners and operators within all sections directly and diagonally offsetting the section where the gas well is located. o The ownership of the nine square miles surrounding the BLT gl well is highly complex because of the many residential lots in the area. Varied subsurface and surface ownership exists, which would require mailing hundreds of notices to the mineral and surface owners in the area. . As part of the Alaska Coastal Zone Management review process, the Department of Governmental Coordination ("DGC") held two public meeting in the Houston/Wasilla area during May and June to inform the public of the proposed Pioneer Unit development, including operations in the BLT gl well. Ocean Energy, Unocal and other state agencies participated in these meetings. 8. The DGC advertised the public meetings and issued public notification of the project in various forms of media publications including postings at local post offices. 9. Unocal sent notice to all owners within a ½ mile radius of the BLT # 1 well prior to the public meetings. CONCLUSIONS: 1. An exception to 20 AAC 25.055(a)(2) is necessary to allow re-entry of the BLT gl well. 2. Production testing of the BLT gl well will not violate the correlative rights of adjacent owners. o A variance from the public notice provisions of 20 AAC 25.055(b) for re-entry of the BLT #1 is warranted in the context of the complex ownership and the extensive notification and public meetings previously conducted. ° If commercial production from the BLT # 1 well is ultimately proposed, the Commission will be required to take further action to offset any advantage that Ocean Energy may have over other producers from the drilling and re-entry of the BLT # 1 well at its exception location. Such action may include, but is not limited to, insuring that drainage from adjacent tracts is prevented or minimized, or insuring that Ocean Energy is allowed to produce no more than a just and equitable share of oil and gas from any common pool. NOW, THEREFORE, IT IS ORDERED: Conservation Order 448 Page 3 August 11, 1999 Ocean Energy's applications for an exception to the spacing requirements of 20 AAC 25.055(a)(2) and the notice provisions of 20 AAC 25.055(b) for the purpose of reentering and testing the BLT #1 well is approved under the following conditions. 1. The BLT #1 exploratory gas well must be tested to determine the well's potential to produce commercial quantities of hydrocarbons. , The BLT # 1 well-may not be commercially produced until the commission takes additional action, upon petition and after notice and hearing, to (a) offset any advantage Ocean Energy may have over other owners by reason of re-entry of the BLT #1 well at the exception location, and (b) allow affected owners to produce their just and equitable share of hydrocarbons. DONE at Anchorage, Alaska and dated August 11, 1999. ~ basekrta ~ i 1C~h~S~nasS ~n(~ nPs'e~'at~ohnaicr~ amnm i s s ion Alaska Oil.-and Gas Cc tservation Commission AS 31.05.080 provides that with)n 20 days after receipt of written notice of the entry, of an order, a person affected by it may file with the Commission an application for reheating. A request for rehearing must be received by 4:30 PM on the 23rd day following the date of the order, or next working day ifa holiday or weekend, to be timely filed. The Commission shall grant or refuse the application in whole or in part within 10 days. The Commission can refuse an application by not acting on it within the 1 O-day period. An affected person has 30 days from the date the Commission refuses the application or mails (or otherwise distributes) an order upon rehearing, both being the final order of the Commission, to appeal the decision to Superior Court. Where a request for rehearing is denied by nonaction of the Commission, the 30 day period for appeal to Superior Court runs from the date on which the request is deemed denied (i.e., 10th day after the application for reheating was filed). Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re: Pioneer Unit - Matanuska Valley Union Oil Company of California (UNOCAL) by letter dated July 13, 1999, requests a spacing exception to the provisions of 20 AAC 25.055(a)(2) for the re-entry of the BLT #1 well in the Pioneer Unit, located adjacent to the Big Lake Road near the Rodda Subdivision. The exception would allow UNOCAL to re-enter and test the BLT #1 gas well within 1500' of a governmental section line. The well will be drilled as a vertical hole from a surface location 1334' from the west line and 795' from the north line of Section 22, T 17N, R3W, Seward Meridian. UNOC~ also requests by letter dated July 13, 1999, a variance from the notice provisions of 20 AAC 25.055(b) that requires notice to be mailed to all owners in governmental sections directly and diagonally offsetting the section in which the well is located. UNOCAL requests the Commission substitute this notice published in the Frontiersman and Anchorage Daily News. UNOCAL is requesting the variance for the following reasons: the proposed activity is limited to drilling and testing only; there has been extensive public notice regarding the Pioneer Unit plan of exploration; UNOCAL has provided notice to all owners within one-half mile of the BLT #1 well; and that before regular production occurs requiring a spacing exception, further notice and public hearing will be provided. A person who objects to the requested variance or spacing exception may file a written protest prior to 4:00 PM, August 4, 1999 with the Alaska Oil and Gas Conservation Commission, 3001 Porcupine Drive, Anchorage, Alaska 99501, and request a hearing on either or both matters. If a protest is timely filed a hearing on the matter(s) will be held at the above address at 9:00 AM on August 19, 1999 in conformance with 20 AAC 25.540. If no protest is filed, the Commission will consider granting the variance and spacing exception without a hearing. Robert N. Christenson, P.E. Chairman Published July 20, 1999 ADN AO# 02014006 July 2, 1999 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 ARCO BLT #1 API# 50-009-20006 Matanuska-Susima Borouo~ Dear Madam or Sir; Enclosed are the original and two copies of the application to drill and the required attachments for the subject well. If you have any questions or need additional information, I can be reached in Denver at (303) 308-8863. Thank you for your time in this manner. Sincerely, Scott M. Webb Regulatory Coordinator Anchora9~ Ocean Energy Resources~ Inc. Amoco Building 1670 Broadway, Suite 2800 Denver, Colorado 80202 (303) 308-8500 Fax: (303) 308-8510 STATE OF ALASKA ALASKA OI/ ND GAS CONSERVATION CC MISSION PERMIT TO DRILL la. Type of work Ddll: Reddll: I lb. Type of well Exploratory: Stratigraphic Test: Development Oil: Re-Entry: X Deepen:I Service: Developement Gas: X Single Zone: X Multiple Zone: 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Ocean Energy, Inc. GL: 100' feet 3. Address 6. Properly Designation Tyonek 1670 Broadway, STE 2800, Denver, CO 80202-4826 ADL 374124 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 793' FNL & 1333' FWL $ e c 2 2-T 17N-R3W Pioneer Unit/ARCO BLT At top of productive interval 8. Well number ,~'(_ Number JZ 8072 793'FNL&1333'FVV1. Sec 22-T17N-R3W Z~..T 1~ At total depth 9. Approximate spud date Amount $200,000.00 793' FNL & 1333' FVVL S e c 2 2-T 1 7N-R3W Upon Approval 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in i~roperty 15. Proposed depth (MD and TVD) property line 1060' feet 300' feet 1919.20 4,050' feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth: feet Maximum hole angle: Maximum sun'ace 1450 psig At total depth (TVD) 1500 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD I'VD MD TVD (include stage data) 19. To be completed for Reddll, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 6200' feet Plugs (measured) CICR + 117 sx true vedical 6200' feet ClCR + 72 sy @ 5160', TOC @ 4,755' ClCR + 185 sx @ 4,755' TOC @ 4,107' Effective depth: measured feet Junk (measured) BP @ 4,096' / BP @ 300' + 200 sx Cement to Surf. true vertical feet Casing Length Size Cemented Measured depth True vedical depth Structural Conductor 321' 20" 1,314 sx 321' 321' Surface 1,700' 13-3/8" 1,400 sx 1,700' 1,700' Intermediate Production 4,494' 9-5/8" 1,117 sx 4,494' 4,494' Liner 1,876' 7" 470 sx TOP: 4,324' Bottom 6,200' Perforation depth: measured Proposed Perfs: 2250' to 2300' & 2732' - 2772' (See wellbore diagram for original perforations) 0~ ' true ver~cal Proposed Perfs: 2250' to 2300' & 2732' - 2772' - 20. Attachments: Filing fee: r-¢¢ Property Plat: ~ BOP Sketch: X Diverter Sketch: Ddlling program: X Ddlling fluid program: X Time vs. depth plot: Refraction analysis: Seabed report: 20 AAC 25.050 requirements: 21. I herby certify that the foregoing is true and correct to the best of my knowledge: Signed: ,~~~~¢~=~=' ~~,. Title: Regulatory Coordinator Date: 7/2/99 - Commission Use Only I I ISee c°ver letter Permit?~,_Number~, ? APIs0_number009_20006- ~ Approval date ~.,,/~"'~ ~ for other requirements Condi[ions of approval Samples required: [ ] Yes ~No Mud log required: [ ] Yes ~No Hydrogen sulfide measures [ ] Yes ,~No Directional survey required [ ] Yes Required working pressure for BOPE [ ]2M; 1~3M; [ ]5M; [ ]10M; [ ]15M Other: by order of ORIGINAL SIGNED.El"f'Commissioner the Commission Date: Approved by c),,~.~,.~ ,~, ,.~- ......... Form 10-401 Rev. 12-1-85 20 AAC 25-005 Submit in triplicate CURRENT PLUG AND ABANDc....,~ENT OF LOWER INTERVAL ALL DEPTHS RKFt 20' 94# H40 STC CASING AT 321' i'.:: BLT #1 WELLBORE DIAGRAM TOP OF CEMENT PLUG AT SURFACE BRIDGE PLUG AT 300' CEMENT VOLUME ABOVE BRIDGE PLUG/ BEHIND 9-5/8' CASING = 224 CU. F-i'. 13-3/8' 68# L80 BTC CASING AT 1700' TOP OF CEMENT AT 1880' TOP OF LINER AT 4324' F:.:: 9-5/8" 47# L80 BTC AT 4494' .F.:E:?. TOP OF CEMENT AT 4600' ¢:"':::"':: ¢2".'?.: F:..':-'.:::: ¢.::::.::: f:..': .'...:: : DST #3 PERFS: 4813'-5146' 4813-74, 4928~54, 4970-90 5024-52, 5060-5146 (221' OF 330') 34' BETWEEN DST #2 AND DST #3 DST #2 PERFS: 5180'-5716' 5180-88, 5198-5219, 5236-48 5264-5329, 5360-62, 5378-88 5406-08, 5436-68, 5518-27, 5552-78 5606-08, 5620-30, 5642-5650 5668-72, 5707-16 (220' OF 536') 80' BETWEEN DST#1 AND DST #2 DST #1 PERFS; 5796'-6010' 5796-581 O, 5822-30, 5844-68 5888-5900, 5963-94, 6004-10 (67' OF 214') 7" 29# L80 LTC Liner @ 6200' PBTD @ 6105' . BP @ 4096' ;,'~]a.s,.ka. 0il & Gas Cons. Anchorage; TOP OF CEMENT AT 4107' RECEIVED MAY 1 5 1992. Alaska 0il & Gas Cons. Comm[s¢O~ Anchorage CEMENT SQUEEZE DST #3 INTERVAL CMT VOL. ABOVE RETAINER = 210 CU. FT CEMENT RETAINER SET AT 4755' CMT VOL. BELOW RETAINER = 85+ CU. FT CEMENT SQUEEZE DST ¢'2 INTERVAL CEMENT RETAINER SET AT 5160' · CMT VOL. BELOW RETAINER = 130+ CU. FT DST #1 INTERVAL CEMENT RETAINER AT 5785' 10.5 LB/GAL BRINE ~ 11.2 PPG BRINE ARCO Alaska, 5/1 1/9 2 FOUND 2' BRASS MONUMENT (S 8g'54'00' W ,3055.93' P74-12 + P79-455) . ~ ;~ ~"' . S 89'59'52" W 25.35.11' COMP. · ........... ~I (S 89'54'00' W 26.36.70' BLM) 419.65' COMP.-../. / (~:..67' P79-,~ss) / I: '"";' "': ~': '~ ;' '; ;' ';' g .- · .... COMPUTED POINT NOTHING SET-" I. , ~'"' '" .:-;......~ ~ .-- . 1333.43' · .......... S 89'58'33' w .-'['ropos~d HLT ;.'fl "¢,'e:; Louati,)n Ir '/:"'4' '" :991) ~'. ..... H_,-< 8, FOUND 2-1/2' ALUM. MONUMENT Z 89'53'4.6' E 1319.59' (S 8g'56'50' E 1.319,85' P79-440) BASIS OF BEARINGS BLM N 89'54.'30' E 2636.26' (2638,19') (;4 ~9'47'.~2' E 2R36.42' P;'4.-61) \ 1914 O/ FOUND 2' BRASS MONJMENT ,' ,/ SEC 2? / FOUND IRON PiN PROPOSED LOCATION OF BLT #1 IS 793' -"ROM THE NORTH L;NE AND 13.33' FROM THE WEST LINE, SECT;O:-: '~'~,.~, fl/N, R3W, S.M.. LOCATION DETAIL SCALE '" , =, 500' ARCO BLT #1 Proposed Re-Entry/Completion Well Detail/Casing Detail NE NW Section 22-T17N-R3W Matanuska-Susitna Borough, AK 2 1) Conductor: 20"/94# / H-40 / Welded @ 321'. Cemented with 1314 sx. 2) Surface: 13-3/8" / 68# / L-80 / BTC @ 1700'. Cemented with 1400 sx. 3) Production: 9-5/8"/47# IL-80 / BTC@4,494'.Cemented with 1117 sx. 4) Liner: 7"/29#/L-80 From 4324'-6200' Cemented with 470 sx. 5) Tubing:2-7/8"/6.5# / J-55 / EUE 8rd @ +- 1500' 6) Packer @ +- 1450' 7) Perforations Between 1,500' and 4,000' 8) TD: 6,200' 9) PBTD: 4,000' 3 4 See attached current completion diagram for plugs and cement retainer intervals. CH&P RIG #19 Hydraulic Oil - 100 gal. Motor Oil - 200 gal. Gear Oil - 100 gal. 1 4700 gal. Diesel fuell 285' bbl. Fresh Water 150 bbl. Brine Tank Light Plant Dog House L Drilling Unit %. .. .. Pipe Racks Brine for Hydromatic - 220 gal. Hydraulic Oil - 260 gal. Mud Pump Diesel Fuel 199 gal. Mud 'Pit 300 bbl. Rig Floor Cat Walk Guylines - 60' back / 45' out from center ./lines - 60' front / 60' out from center RECOMPLETION PROCEDURE ARCO BLT #1 NENW Sec. 22, T17N- R3W Matanuska-Susitna Borough, Alaska General The Arco BLT#1 was drilled in Matanuska-Susima Borough during February 1992 by ARCO Alaska as a exploratory well to a depth of 6,200', but P&A'ed during March 1992 after an unsuccessful test of deeper zones. The 7" 29#/ft L80 LTC liner from 4,324' to 6,200' will not be re-entered and will remain abandoned below a CIBP at 4,096'. The attached re-entry and recompletion procedure is to perforate underbalanced and test two intervals to produce natural gas from behind the 9-5/8" 47#/t~ LB0 BTC casing in the Arco BLT #1 wellbore. Well Data GL: 100' KB: 130' LGRTD: 6,192' Surface Casing: 40jts of 13-3/8" 68 #/Ft L-80 BTC Casing to 1,700' KB. Cemented to surface with 1400 sxs premium cement with good returns. Production Casing: 9-5/8" 47 #/Ft L-80 LT&C Casing to 4,494' KB. Cemented to TOC of 1,880' with 1,117 sxs Premium Cement. Displaced with fresh water. Set slips with 50,000# over string weight. 9-5/8" Casing Data Description 9-5/8" 47 #/Ft L-80 LT&C ID Burst Capacity 8.525" 6,870 psi 0.0732 bbls/Ft RECOMPLETION PROCEDURE ARCO BLT #1 NENW Sec. 22, T17N - R3W Matanuska-Susitna Borough, Alaska Procedure 1.) Clean and blade location as required and dig out to a depth of 4 feet around the wellhead. Set rig anchors. MIRU workover rig with pump and tank. Unload, rack, and tally 2-7/8" J-55 tbg. 2.) Drill out surface cement plug in the 9-5/8" casing to the CIBP at 300' with an 8-1/2" bit. POOH with tbg and bit. NU 13-3/8" 3M SOW casing head and 3M BOPE. Pressure test BOPE and 9-5/8" casing to 2,500 psi. 3.) Drill out the CIBP at 300' and clean out to PBTD (CIBP) at +/- 4,096' KB with an 8-1/2" bit. Circulate clean w/wtr. TOH. Pressure test casing to 2,500 psi. 4.) RIH with bit and scraper to PBTD. Circulate clean with 2% KC1 wtr. POOH w/tbg, scraper and bit. 5.) RU wireline. Make a gauge ring/junk basket nm from 4,000' to 1,700'. Run CBL-GR-CCL from PBTD to 200 ft above TOC. 6.) RIH, correlate and wireline set a tbg retrievable Baker Retrieva-D Pkr, shock sub and a 4-1/2" Alpha- Jet TCP system to perforate the coal seam interval from 2,732' to 2,772' (40') with 5 jspf, 135/45 degree phasing, and 32 gm charge to achieve a 0.45" perforation hole. Correlate depths to Western Atlas CDL/CN/GR dated 1/30/92, Run #3. RD wireline. TCP will be fired during Step #8. 7.) RIH w/5' seal section on 2-7/8" 6.5#/fi EUE 8rd J55 tbg. Sting into and space out above the packer set in step//6. Swab fluid level down to 700' to achieve +/-500 psi of underbalance to the anticipated formation pressure of +/- 1,400 psi based on a gradient of 0.51 psi/ft. NU choke, lines to a flare pit, test equipment, and tank to handle potential gas/fluid flow from the perforated interval. Place liners under lines, test equipment and tank as necessary. 8.) Hold safety meeting to prepare for potential pressure after perforating. Drop bar to fire TCP system. Record any change in casing pressure or fluid level. Perforation depths correlated to Western Atlas CDL/CN/GR dated 1/30/92, Run #3 as noted in Step #6. 9.) Swab if necessary to kick off flowing production. Flow test well. -Record rates and pressures. Report test data to Denver office by 7:00 am every morning. 10.) Kill well as necessary. POOH with tbg and seal assembly. Keep hole full. 11.) RIH w/retrieving head on 2-7/8" tbg. Latch onto and release Retrieva-D Pkr. POOH w/tbg, pkr and TCP system. Keep hole full. RECOMPLETION PROCEDURE ARCO BLT/ti NENW Sec. 22, T17N - R3W Matanuska-Susitna Borough, Alaska Procedure (continued) 12.) RU w/reline. RIH, correlate and wireline set a tbg retrievable Baker Retrieva-D Pkr, shock sub and a 4-1/2" Alpha-Jet TCP system to perforate the sandstone interval from 2,250' to 2,300' (50') with 5 jspf, 135/45 degree phasing, and 32 gm charge toachieve a 0.45" perforation hole. Correlate depths to Western Atlas CDL/CN/GR dated 1/30/92, Run #3. RD wireline. TCP will be fired during Step #14. 13.) RIH w/5' seal section on 2-7/8" 6.5#/fi EUE 8rd J55 tbg. Sting into and space out above the packer set in step #12. Swab fluid level down to 750' to achieve +/-500 psi of underbalance to the anticipated formation pressure of +/-1,150 psi based on a gradient of 0.51 psi/ft. NU choke, lines to a flare pit, test equipment, and tank to handle potential gas/fluid flow from the perforated interval. Place liners under lines, test equipment and tank as necessary. 14.) Hold safety meeting to prepare for potential pressure after perforating. Drop bar to f'zre TCP system. Record any change in casing pressure or fluid level. Perforation depths correlated to Western Atlas CDL/CN/GR dated 1/30/92, Run #3 as noted in Step #12. 15.) Swab if necessary to kick off flowing production. Flow test well. Record rates and pressures. Report test data to Denver office by 7:00 am every morning. 16.) Kill well as necessary. POOH with tbg and seal assembly. Keep hole full. 17.) RIH w/retrieving head on 2-7/8" tbg. Latch onto and release Retrieva-D Pkr. POOH w/tbg, pkr and TCP system. Keep hole full. 18.) RIH with a production system design based on swab/flow test data. ND BOPE. NU well head and leave well in a shut-in status. 19.) RD & MOL 20.) Install and test Production facilities on surface as required for predicted production rates and pressures. Tie facilities into the pipeline. 21.) Notify AOGCC of plans to start production. Place well on production. BLOWOUT PRE~ 'NTER SYSTEM Pioneer Unit Ocean Energy, Inc. Fill Line Flow Line Diverter Rating: 3,000 psi Active 5,000 psi Static Choke Manifold Assembly for 3M WP System To Pit and/or Mud/Gas Separator Adjustible Choke I Annular I I I I R-Pipe Rams I I I I I R-Blind Rams I I !Spool! J K,,,L,nesJ 3000 PSI WP Choke Line Blowout Preveter Stack Outlet Choke Line Bleed Line to Pit To Pit Adjustible Choke Ocean Energy Resources, Inc. Alaska Coal Bed Methane Drilling Program Pioneer Unit ARCO BLT # 1 Blowout Prevention Equipment 13-3/8" BOP Equipment 1 each 13-3/8" X 3,000 psi wp single type pipe ram. 1 each 13-3/8" X 3,000 psi wp double type blind rams. 1 each 13-3/8" X 3,000 psi wp annular preventer. 1 each 13-3/8" X 3,000 psi wp drilling spool with 2 each 4" side outlets (choke and kill), HCR and manual vanes on choke line and two manual valves on kill line. 1 each BOP control unit with 80 gallon volume tank, with 3, 10 gallon accumulator bottles and nitrogen back-up system. 1 each 3,000 psi choke manifold Diverter Rating: Active 3,000 PSI Static 5,000 PSI Found survey monument N89"42'16"E 26,36.01 North Line Section 22 ~ ~Proposed Surface ~ , Facilities I -J ~Well 1334 -~ ~ Not to ScoI~ ARCO BLT ,,J,/~l GRID N: 2760190.15~~~ ~ GRID E: 554287.99~W ~ LATITUDE: 61'5~'16.0~6::1 LONGITUDE: 149'48'12.258'~ ~ ASP ZONE 4 NAD27 Z GL : 100' LLI ~ * Z Z I'~ 1) Basis of Horizontal Coordinates State of Alaska DOT&PF Oeoreferencing Project OPS Control Stations BigL & 040. 6~21/99 Revised R/W Width DA TE DESCRIPTION OCEAN ENERGY, INC. ARCO BLT SURFACE LOCATION 1,334' FWL end 795' FNL msm BY T17N, RSW, S.M., AK Prepored For: Ocean Energy Inc. 1670 Broadway Suite 2800 Denver, CO 80202 Surveyed by:. 993060 Job No: ....... McLANE CONSULTING GROUP Engineers, Surveyors ond Plonners P,O, Box 468 Soldotno, AK 99669 99-20 June 19, 1999 Field Book No. Dote: STATE OF ALASKA ^L.ASKA OIL AND GAS CONSERVATION COMMISSION DESIGNATION OF OPERATOR 20 AA'c 25.020 Name and Address of Owner: Union Oil Company of California PC) Box 196247 (909 W. 9th Avenue) Anchorage, AK 99519-6247 Notice is ereby given of a designation of operatorship for the oil and gas property described below: Legal description of property: · See attached Exhibit -- ~ ¢4-~,.. Property Plat Attached Name and Address of Designated Operator: Ocean Energy Resources, Inc. 1001 Fannin, Suite 1600 Houston, Texas 77002 Effective date designation: July 1, 1999 Acceptance of operatorsh/ip for the above-described property with all attendant responsibilities and obligations is hereby acknowledged. Signed .~ Date July 2, 1999 Name (printed) Hank Wood Title (printed) At to rney-in-Fac t The owner hereb~ certifies that the foregoing is true and correct, Signed LL,L.~__, t.~,-~ ~ Name (printed) Kevin A. Tabler Date \ -~ (~ : Title (printed) Attorney-in-Fact Date Approve ~ Approved ~ ..... _ _ _ .~2.~;;::::::~:~ ~~ ~ ~ Form 10--411, Rev. 01-08-92 Date Submit in Duplicate OCEAN ENERGY RESO"~qCES, INC. 410-17th Street, S 1400 Denver, Colorado 80202 (303) 573-5100 PAY THE SUM OF One hundred and 00/100 Dollars TO THE ORDER OF NationsBank, I' ' Atlanta, Dekalb County, orgia DATE 64-1278~611 No. 0500137107 JUN 18,1999 AMOUNT *****$100.00 VOID AFTER 90 DAYS ALASKA OIL & GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, AK 99501 ,'O SOO i, :~ ? i,O ?,' '.' O & i, l, i, 2788~: ~;=g =t=t'~ ;=O=i?"' OCEAN ENERGY RESOURCES, INCA10-17th Street, Suite 1400 * Denver, Colorado 80202 ° (303) 573-5100 061499A 06/14/99 342678 APD FOR ARCO 100.00 100.00 BLT #1 RE-ENTRY, ALASKA I::ii!i! i:i::iiiiii ,lOO.OO ,lOO.OO WELL PERMIT CHECKLIST __ dev ~ redrll ~ serv __ wellbore seg ann. disposal para req __ FIELD & POOL ~'/~,~'~ ~ ADMINISTRATION COMPANY~_,c"_~-~. ~"~¢_~, ,~JVELL NAME~ #..~ ,,~ PROGRAM; exp INIT CLASS /-~..~_~ ~ ,- ,~j.~ G ENGINEERING DATE., / 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to '~ {,~ o ~:'~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ ON~ AREA ~;~-~"2'_J UNIT# . ,~'/' ,5~, ~;'"'~..._~ ON/OFF SHORE U / N/~ Y N 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. APPR D T 30. Permit can be issued w/o hydrogen sulfide measures ..... 31. Data presented on potential overpressure zones ....... Y N 32. Seismic analysis of shallow gas zones .............. 33. Seabed condition survey (if off-shore) ............. 34. Contact name/phone for weekly progress reports [exploratory onl~l/Y N ANNULAR DISPOSAL APPR DATE 35. With proper cementing records, this pla. m-" (A) will contain waste in a suitable~iving zone; .... .>.?.""~ Y N (B) will not contaminate fre.~ter; or cause ddllin~~... Y N to surface; ~ / (C) will. not im~chanical integrity of the.y~,ell' used for disposal; Y N (D) will no~SCdamage producing fo~mpair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular, COMMISSION: RP(". BEW ~'~ WM / DWJ .'t~'K--- .... JDH ~ .... / RNC--~ CO Co Comments/Instructions: c:\msoffice\wordian\diana\checklist