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Home My WebLink About199-066,.~„% GEOIOGiC MATERIALS CENTER NEW INVENTORY ' i``""t~` INV'~.N'f'ni21FI'f av~ z { --t''~ ~qq-nG~ 6MC LOCA71 ON WELL NAME WELL NO API SE7 NUM6ER OFERATORt TYPE ME7W00 TOP BOTTOM &OX COMMENTS d ~•: 1- ci A,t i?' f~lr2 r~ -- ~ot~~ ~'z~,YP~~ t'<~d 1;;` ' f;4= F` I ,. I ,~ c ~` t ~, , ~~. ~< ~.: __-- _~.~... ..w .._...-~ Page ' L~OtthTi~fl ~~' f'ff,UL Ir~`f~'t2 ~~v~~ t'1i14fD9~ ~iV~ U C. L ~i ~ &~~~ t _ .... , A e e MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ----71/" 5'/l1/~ P. I. Supervisor "'Y1 DATE: May 8, ~' ~Ð(¡) ~l\q'b(,(P 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 PTO: 202-177 Baranoff 04 PTO: 202-178 Cook 01 PTO: 202180 Lowell 02 PTO: 202-179 1702-14CC PTO: 199-065 1702-150A WOW PTO 199-064 urt02-1500 PTO: 199~6 Cornhusker 04 PTO: 202-181 RL Smith 03 PTO: 202-182 OL Smith 01 PTO: 202-184 Stromberg 02 PTO: 202-183 BL T 01 PTO: 199-068 ., ",~r :ñ,.:Alt: \1"';_ - 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 CO NON-CONFIDENTIAL Wen location clearance; off Vine Road in Water Well WELL COMPLETION OR RECOMPLETION REPO '¡'\- ....... 1 1a. Well Status: OilU GasD Plugged ~ Abandoned 0 Suspended D WAGD 1b. Well{ge!;r~. M&Æ-- 20AAC 25.105 20AAC 25.110 It D~velopment 7 ploratolY'B- GINJD WINJD WDSPL D No. of Completions Other ~JH¡icWj~Ué'" /"'. Stratigraphic TestD 2. Operator Name: 5. Date Comp., Susp., or 12. ~__il'!~017?miSS¡on Pioneer Natural Resources Alaska, Inc. Aband.: Aug 19,2005 3. Address: 6. Date Spudded: 13. API Number: 700 G Street, Suite 600 Anchorage, AK 99501 September 16, 1999 50-009-20017-00 / 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 793' FEL, 171' FSL, See 15, T17N, R2W, SM September 23, 1999 1702-15DD / Top of Productive Horizon: 8. KB Elevation (ft): 15. Field/Pool(s): Same 264 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- 569040 y- 2761298 (NAD 27) Zone- 4 4228 MD, TVD ADL374117 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 UNo ~ 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 13.375 68 J-55 Surface 35 Surface 35 17.5 30 sx class G None '" -!':625 36 J-55 Surface 679 Surface 679 12.25 400 sx class G None 7 23 CF-50 Surface 4212 Surface 4212 8.75 730 sx class G None 23. Perforations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and NumbeY;·1fl'Töl1e;·state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) None 2.875 2175 NA 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USEp SCANNEf' G l' 8 2005 938-4052 152 bbl Type I cement pumped for sqz / , 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: IGas-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 ORIGINAL ~ ~OOJYrS: I Form 10-407 Revised 12/2003 CONTINUED ON REVERSE 10 L I ð1Jl _ STATE OF ALASKA . ALASKA <YAND GAS CONSERVATION COMMISSI MtNEi ~.lúi(.p ,.,,0 \ to\ Js- ~ 28. GEOLOGIC MARKERS _ 29. /' ~~ORMATION TESTS NAME MD,- ~ TVD Include and briefly sum~e 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\~~-- Phone: 907-343-2111 Date: lO/J7/0S:- , 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 1a: Classification of Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for I njection, 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 1702-15DD Plug and Abandonment Operations Summary August 10, 2005 Safety meeting. Check well, water to surface in tubing and annulus and dead. Establish injection pressure into perforations, 2.5 bpm, 900 psi. Pump 5 bbl gel pad into 2-7/8 x 7 inch annulus. Follow gel pad with 2.5 bbl water. Mix and pump 63 bbl, 15 ppg Type I cement down annulus squeezing perforations with 900 psi at 2.5 bpm. Shut in annulus and swap cementing line to tubing. Mix and pump 89 bbl cement down tubing, squeezing remaining perforations at 950 psi, 2.2 bpm. Shut in well at 350 psi. SDFN. August 11, 2005 Set top job in conductor casing. August 13, 2005 Dug out well cellar and cut off well to 5 feet below grade. Cement to surface in all casings. Had to use 6x5 centrifugal pump to continuously dewater excavation during cut off and welding operations. August 18, 2005 Chuck Sheve of the AOGCC inspected 1702-15DDwell for P&A. August 19, 2005 Welded marker plate on well and backfilled excavation. - 1 - Pioneer Natural Resources Alaska, Inc. 1702-15DD Plug and Abandonment Photos Photo 1: Cementing equipment rigged up on well. - 2 - Photo 2: Excavating around well prior to cut off of well 1702-15DD. Note substantial water flow into excavation. - 3 - Photo 3: 1702-15DD well cut off and cement to surface with dewatering in progress. Photo 4: 1702-15DD with marker plate installed. -4- Pioneer Unit 1102·15DD Final Well Schematic well 1702·15DD API 50-009-20017 Qtr/Qtr Sec 15 Pioneer Natura! Resources Alaska, Inc. Twp 17N Rng 2w Size I Weig Depth County Matanuska,Susitna State Alaska ing 9-5/8 679 Field Pioneer Unit Country USA 7 LT&C 1 4212 8Rd T 2175 ~LenQth 00 10 4052 N/A 4010 4 N/A N/A 4010-4014 perf 5 spf 3916 ~N/A 3916-3922 perf 5 spf alpha jet 4 3884 I N/A~890 perf 5 spf alpha jet 5 3748 8 N/A N/A 756 perf 5 spf alpha jet, SQUEEZED 6 2176 1 2.875 2.205 XN Nipple 7 ~ 2.3 4.5 8.188 Gemco Md 715 lied out) 8 12 N/A N/A perf 9 1420/: 8 N/A perf 10 10IN/A N/A 5 spf alpha jet, SQUEEZED 11 I 21751 2.441 2.8 2-7/8 J-55 EUE TbQ 12 Surface I cuttoff five feet below ground level. H I I I 12 Created by STG 518/03 Modified by JRM 14-sep-2005 ) ) 1 qq'- Oft,[o Pioneer Natural Resources Alaska, Inc. Plug and Abandon Procedure Pioneer Unit 1702-15DD Well Revision #1, August 5, 2005 Pioneer Unit well 1702-15DD was drilled in 1999 by Ocean Energy as a gas well. The well has a 13-3/8 inch conductor set at 35 feet, 9-5/8 inch surface casing set at 679 feet and 7 inch production casing set at 4212 feet. The cement job on the 9-5/8 casing did not have surface cement returns and the 13-3/8 x 9-5/8 annulus was cemented by top job from 60 feet back to surface. The 7 inch casing was cemented to surface through a DV collar that was set at 2109 feet. Inside the production casing, 2-7/8 inch tubing is hung from surface to 2176 feet with no packer. The well is also perforated at various intervals from 938 to 4056 feet. An existing gravel pit operation on Vine Road surrounds the location of the well. The current 1702-15DD well schematic is presented in Attachment 1. Pioneer Natural Resources Alaska, Inc. (Pioneer) proposes the following P&A procedure to plug the well in accordance with AOGCC regulations. The proposed final 1702-15DD well diagram is presented in Attachment 2. 1. Verify all permit paperwork is in place and give AOGCC 24-hour notice of intent to begin well work operations and intent to cement well and give AOGCC representative chance to witness same. 2. Mobilize necessary equipment and personnel to location. 3. Check for pressure on casing and tubing. Expect to see same pressure on tubing and tubing/casing annulus. Circulate out any trapped gas and ensure well is dead before starting cement job. Check for pressure on 9-5/8x7 inch annulus and bleed off if necessary. Expect no pressure on annulus due to reported surface cement job on 7 inch casing. 4. Rig up high pressure cementing lines on tubing and test same to 3000 psi. Verify ability to circulate down annulus and up tubing and inject into perforations with casing wing valve shut in. 5. Mix up a 5 bbl high viscosity bentonite gel plug and pump into casing taking returns out tubing. Follow gel plug with 1 bbl water. 6. Mix and pump 63 bbl, 15 ppg, Type I cement down the 7 x 2-7/8 inch annulus taking returns out tubing. Shut in annulus and tubing. Mix and pump an additional 89 bbl cement down tubing into perforations below tubing tail. Shut in tubing when all cement pumped. Clean up equipment and use cement rinsate as injection test fluid on next well or dispose of cement rinsate in sanitary sewer. WOC. 1702-15dd P&A procedure rev I.doc - I - ·SCj\NNE]~ i_\J ¡G ,1 ·:)1' ?ÎJnh ¡ '-" ,.' } ~ L~ ud " ) 7. Excavate around casing to minimum six (6) feet below existing ground level. Install guillotine saw on well and cut off well a minimum of 5 feet below grade or original ground level, whichever is deeper. Remove wellhead for backhaul to D&J yard. Perform top job or any unfilled annuli with cement. Collect photo documentation of surface cement and cutoff well. 8. Weld on well ID marker plate (1/4" x 24" x 24") with the following information bead welded on plate: Pioneer NRA APD: 199-066 Pioneer Unit 1702-15DD API: 50-009-20017-00 Backfill well excavation and grade for positive drainage. Perform complete site inspection immediately after P&A operations if AOGCC inspector is available. I702-I5dd P&A procedure rev l.doc - 2 - e e MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg, P. I. Supervisor /---..~ I / K /,/ ,,--- \"r¡' i t j Cl i - ) ,..'") ---.- , \?I'~) 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 15DD PTD# 199-066 BL T-01 PTO# 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 170214CC.JPG 1702 150A-WO .JPG 1702 15 DO .JPG BL T-01. JPG ¡¡;;;,.~.r. &Ìh(¡;"~~\ $' Ii) ~¡ 2r1Dí ,-,~q-\}U\J~'U..~ '\,;;:~ i:"'~ .¿. ',\oJ'" ~ Willow Fishhook # I Cement Pioneer ¡ to Plate Pioneer ! 702 ¡ to Surface Pioneer! 702 15DD Cement to Surface 3 ì:, j ) S~.~J:ect::rninqrI1l9~itiG~ti9q~to F>Jpn~er. U. nit.P&f\9~rD~nfing:prOgrams.:··. . ~r~m: J~s~~rv1qrr~~srE:1r~j~~~~@1têirweatþer~com:>:.·· . D~t:·SatQpð4····ZQQq:~:.1:16:()þJ.O$OO . Hi Winton, attached are revised P&A procedures tor the Pioneer Natural Resources Alaska, Inc.1702-1500, 1702-150A WOW and 1702-14CC wells. These revisions simply break the cementing operations into two separate cementing batches versus the original plan ot pumping one large cement job and will not change the final proposed P&A drawings. Please contact me with any questions or comments. 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 1702-14CC P&A procedure rev 1 Content-Type: application/pdt Content-Encoding: base64 1702-15DA WDW P&A procedure rev 1 Content-Type: application/pdt Content-Encoding: base64 Content-Type: appl ication/pdt 1702-15dd P&A procedure rev 1.pdf Content-Encoding: base64 ~. TF[Æ' ,iŒ II' Uf UJ\ . f r. , ! " \ JJ I ') rm í-p fÆ"~ 11 j,~ ((ù r~, !Æ(A ¡ IUI ¡ lJ' Þ ¡' U 1 Illft!J '~~! i: Ii U'I \::::)ll l, \~Uì\~!! I, ') FRANK H. MURKOWSKI, GOVERNOR AIASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Joe Polya Pioneer Natural Resources Alaska, Inc. Senior Staff Drilling Engineer 700 G Street, Suite 600 Anchorage, Alaska 99501 nit 0 ~~. \V\ Re: Pioneer Unit 1702-15DD Sundry Number: 305-196 'f:"C,fl'N' N" E"r'~ 2 5 200r ~ "h . U JUL ':,) ~ - '. ,) 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 a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Daniel T. Seamount, Jr. Commissioner "d, DATED this2.2-day of July, 2005 Enc!. ) Joe Polya Sr. Staff Drilling Engineer 700 G Street, Suite 600 Anchorage, AK 99501 Telephone: 907/343-2111 Fax: 907/343-2190 July 20, 2005 Mr. Winton Aubert Alaska Oil and Gas Conservation Commission 333 West ¡th Avenue Suite 100 Anchorage, AK 99501-3539 RECEIVED JUl 2 0 Z005 Alaska Oil & Gal Cons_ 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: · Willow Fishhook #1 Well, · 1702-1500 Well and · 1702-14CC Well. Pioneer has awarded the contract for this work to Fairweather E&P Services, INC. Fairweather's schedule proposes P&A operations for these three wells to commence August 5th, 6th, and 9th, respectively. Thank you for your assistance in this matter. Respectfu lIy, Joe Polya ) ) July 19, 2005 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 -1702-15DD Well Plug and Abandon Dear Mr. Aubert: Attached is the 10-403 form requesting approval to Plug and Abandon the 1702- 1500 well. Pioneer Natural Resources acquired the Pioneer Coal Bed Methane Project through the acquisition of Evergreen Resources Corporation. Evergreen Resources attempted various stimulation techniques in an effort to produce the __ methane from these wells; however, the wells 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, .C:Î\~ ,,'oe Polya Sr. Staff Drilling Engineer Pioneer Natural Resources Company 700 G Street, Suite 600 Anchorage, AK STATE OF ALASKA C¡If...,. )-DS ~~Oiî\7EbZ.'lz,oOÇ ALA~t<A OIL AND GAS CONSERVATION COMMlvSION ' APP)-ICATION FOR SUNDRY APPROVAL JUl 202005 Abandon l:::J Suspend U ~~e~~a~;h~~~wn U Perforate U ^Iaskø Qjb~~ Cons. COlltJ}iMi~ Alter casing D Repair well D Plug Perforations D Stimulate D Time ExtensioA\~Orage Change approved program D Pull Tubing D Perforate New Pool D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Class: µ.iG'Y 5. Permit to Drill Number: Pioneer Natural Resources Alaska, Inc. Development ~ Exploratory.f3- 199-066'/ 3. Address: Stratigraphic D Service D 6. API Number: 700 G Street Suite 600 Anchorage, AK 99501 50-009-20017 /" 7. KB Elevation (ft): 9. Well Name and Number: KB 264 feet 1702-15DD / 1. Type of Request: 8. Property Designation: Private 11. Total Depth MD (ft): Total Depth TVD (ft): Length nfa 35 feet 679 feet nfa 4212 feet nfa ') 10. FieldfPools(s): Pioneer Unit PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): Size nfa 12.750 inches 9.625 inches nfa 7.000 inches nfa Casing Structural Conductor Surface I ntermed iate Production Liner Perforation Depth MD (ft): 938 - 4056 Packers and SSSV Type: None 12. Attachments: Description Summary of Proposal U Detailed Operations Program EI BOP Sketch D 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Perforation Depth TVD (ft): 938 - 4056 Date: Burst nfa nfa 3520 psi nfa Junk (measured): NONE Collapse nfa nfa 2020 psi nfa NA J55 Plugs (measured): Conditions of approval: Notify Commission so that a representative may witness BOP Test D Form 10-403 Revised 11 f2004 2-7/8" 6.4 ppf Packers and SSSV MD (ft): None 13. Well Class after proposed work: (.;,iY" Exploratory..!23"' \fJ. Development 15. Well Status after proposed work: 7)2.5 Oil D Gas D ,r' WAG D GINJ D MD TVD nfa n/a 35 feet 35 feet 679 feet 679 feet nfa n/a 4212 feet 4212 feet nfa n/a Tubing Size: Tubing Grade: Sundry Number: NA nfa nfa Tubing MD (ft): 2175' MD Plugged WINJ [!( U Service D EI Abandoned EI D 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 r'\\)'~J Phone 907-343-2111 Date 7'1.0' z,006' .....\ COMMISSION USE ONLY Plug Integrity D Other: -~~..../?~ Mechanical Integrity Test D Location Clearance [M"" Subsequent Form Required: 1 ö -- 4-07. APProvedbØ~ RBDMS BFL .JUL ? 5 2005 APPROVED BY uMRnj\ N A L COMMISSION Date: 7 / 24 5 Submit in Duplicate ) Pioneer Natural Resources Alaska, Inc. Plug and Abandon Procedure Pioneer Unit 1702-15DD Well Pioneer Unit well 1702-15DD was drilled in 1999 by Ocean Energy as a gas well. The well has a 13-3/8 inch conductor set at 35 feet, 9-5/8 inch surface casing set at 679 feet and 7 inch production casing set at 4212 feet. The cement job on the 9-5/8 casing did not have surface cement returns and the 13-3/8 x 9-5/8 annulus was cemented by top job from 60 feet back to surface. The 7 inch casing was cemented to surface through a DV collar "../ that was set at 2109 feet. Inside the production casing, 2-7/8 inch tubing is hung from surface to 2176 feet with no packer. The well is also perforated at various intervals from 938 to 4056 feet. An existing gravel pit operation on Vine Road surrounds the location of the well. The current 1702-15DD well schematic is presented in Attachment 1. Pioneer Natural Resources Alaska, Inc. (Pioneer) proposes the following P&A procedure to plug the well in accordance with AOGCC regulations. The proposed final 1702-15DD well diagram is presented in Attachment 2. 1. Verify all permit paperwork is in place and give AOGCC 24-hour notice of intent to begin well work operations and intent to cement well and give AOGCC representative chance to witness same. Verify that a variance from the AOGCC has been obtained for leaving the lower perforations in the well unsqueezed before starting work. /" 2. Mobilize necessary equipment and personnel to location. 3. Check for pressure on casing and tubing. Expect to see same pressure on tubing and tubing/casing annulus. Check for pressure on 9-5/8x7 inch annulus and bleed off if necessary. Expect no pressure on annulus due to reported surface cement job on 7 inch casing. / 4. Rig up high pressure cementing lines on tubing and test same to 3000 psi. Verify ability to circulate down annulus and up tubing and inject into perforations with casing wing valve shut in. Mix and Pum6y6bl, 15 ppg, Type I cement down tubing taking returns out annulus. Monltór returns for lost circulation. ¡W'~en good cement returns at surface, shut in annulus and squeeze an additional\:z7~bl cement down tubing into perforations below tubing tail. Shut in tubing when all cement pumped. In the event that cement returns are lost while pumping the initial 81 bbl of cement, pump entire cement program as planned, then esta9fÍSh injection down the casing/tubing annulus and bullhead squeeze same wit~ 5J/bbl additional cement. Clean up equipment and use cement rinsate as injectioiltest fluid on next well or dispose of cement rinsate in sanitary sewer. WOC. / 4. 1 702-15dd P&A procedure.doc - 1 - 7/17/2005 10:46 PM ) ) 7. Excavate around casing to minimum six (6) feet below existing ground level. Install guillotine saw on well and cut off well a minimum of 5 feet below grade or / / original ground level, whichever is deeper. Remove wellhead for backhaul to D&J yard. Perform top job or any unfilled annuli with cement. Collect photo documentation of surface cement and cutoff well. 8. Weld on well ID marker plate (1/4" x 24" x 24") with the following information bead welded on plate: Pioneer NRA APD: 199-066 Pioneer Unit 1702-15DD API: 50-009-20017-00 / Backfill well excavation and grade for positive drainage. Perform complete site inspection immediately after P&A operations if AOGCC inspector is available. 1702-15dd P&A procedure.doc - 2 - 7/17/2005 10:46 PM ) Attachment 1: Pioneer Unit 1702-15DD Current Well Schematic PBTD 4120 Well 1702·15DD API 50-009-20017 Qtr/Qtr See 15 Pioneer Natural Resources Alaska, Inc. Twp 17N Rng 2w Size Weight Grade Thread Depth County Matanuska,Susitna State Alaska Casing 9-5/8 35 ppf J·55 ST&C 679 Field Pioneer Unit Country USA Casing 7 23 ppf CF-50 LT&C 4212 Tubing 2-7/8 6.4 J·55 8Rd 2175 No. I Depth I Length I OD I ID Description 1 4052 4 N/A N/A 4052-4056 perf 5 spf alpha jet 11 2 4010 4 N/A N/A 4010-4014 perf 5 spf alpha jet 3 3916 6 N/A N/A 3916-3922 perf 5 spf alpha jet 4 3884 6 N/A N/A 3884-3890 perf 5 spf alpha jet 5 3748 8 N/A N/A 3748-3756 perf 5 spf alpha jet 6 2176 1 2.875 2.205 XN Nipple 7 2109 2.3 4.5 8.188 Gemco Md 715E stage collar (drilled out) 9 8 1948 12 N/ A N/A 1948-1960 perf 5 spf alpha jet 9 1420 8 N/A N/A 1420-1428 perf 5 spf alpha jet 10 938 10 N/ A N/A 938-948 perf 5 spf alpha jet 11 2175 2.441 2.875 70 jts 2-7/8 J-55 EUE Tbg 8 7 6 5 4 3 2 Created by STG 5/8/03 Modified by JRM 7/18/05 ) ) . ' Attachment 2: Pioneer Unit 1702-15DD Proposed Final Well Schematic '12 Well 1702-15DD API 50-009-20017 Qtr/Qtr See 15 Pioneer Natural Resources Alaska, Inc. Twp 17N Rng 2w Size Weight Grade Thread Depth County Matanuska,Susitna State Alaska Casing 9·5/8 35 ppf J·55 ST&C 679 Field Pioneer Unit Country USA Casing 7 23 ppf CF·50 LT&C 4212 Tubing 2·7/8 6.4 J·55 8Rd 2175 No. I Depth I Length I OD I ID Description 1 4052 4 N/A N/A 4052-4056 perf 5 spf alpha jet, SQUEEZED 2 4010 4 N/A N/A 4010-4014 perf 5 spf alpha jet, SQUEEZED 3 3916 6 N/A N/A 3916-3922 perf 5 spf alpha jet, SQUEEZED 4 3884 6 N/A N/A 3884-3890 perf 5 spf alpha jet, SQUEEZED 5 3748 8 N/A N/A 3748-3756 perf 5 spf alpha jet, SQUEEZED 6 2176 1 2.875 2.205 XN Nipple 7 2109 2.3 4.5 8.188 Gemco Md 715E stage collar (drilled out) 9 8 1948 12 N/A N/A 1948-1960 perf 5 spf alpha jet, SQUEEZED 9 1420 8 N/A N/A 1420-1428 perf 5 spf alpha jet, SQUEEZED 10 938 10 N/ A N/A 938-948 perf 5 spf alpha jet, SQUEEZED 11 2175 2.441 2.875 70 jts 2-7/8 J-55 EUE Tbg 12 Surface Well cuttoff five feet below ground level. 8 7 6 5 4 3 2 PB/TD 4120 Created by STG 5/8/03 Modified by JRM 7-18-2005 Field: Well Job# Log Description Date BL ¡cg5 -c5C 2V-12 10942845 PROD PROFILE/DEFT 02/16/05 1 t8tf-/53 2D-03 10922538 PROD PROFILE/DEFT 02/06/05 1 ~&è -2.i 0 1 D-39 10942838 INJECTION PROFILE 02/11/05 1 /g:¡ -t>l~- 2V~10 10942846 PROD PROFILE/DEFT 02/17/05 1 ~Ol- Jg5 1C-131 10942848 INJECTION PROFILE 02/19/05 1 /7e -/~I 1 A-19 10942839 PRODUCTION PROFILE 02/12/05 1 /~9-0(¿) 2N~308 10942843 PRODUCTION PROFILE 02/14/05 1 19/.. ~ 1L-17 10942850 INJECTION PROFILE 02/21/05 1 2.0lf--i? b 1 B-15A 10922540 SCMT 02124/05 fl ¡'" ()fv (¡;; 1 L-24 (REDO) 10942834 RSTWFL & PPROF 01/26/05 1 / ir--éJ~~ Schlumberger NO. 3357 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth SCANNED JUN 1 7 2005 Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Kuparuk Color CD 1 S'GNdld,! áLÁ~ DATE: ~þ- Please sign and return'l'one copy of this transmittal to Beth at the above address or fax to (907) 561 ~8317. Thank you. 02/28/05 .~ ~ Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well If~" I7c C-29A 1-'11- I;; E-25 fC¡3~t2.'1 G-02A oJ..iH,. /Lfi{ W-27 A "e-ot4 D-25A (---.. ,'(fq -()()~ DS 15-25A' '~ ~_Ø'lc..E~39A '\ 02-16B I 9,.. () l! C-25A ~cl.{-:LÐ1 E-17A Zotj" i<b~ C-41A j :'c," -(¡ìJ)- DS 07-30A :~<?1"DS 15-38A i.tilf-//P{ 02-28A ,;:¡5-i~j" D-11A 2 (tf - 2Ji) DS 05-24A Job# 10715422 10715423 10715424 10670031 10854314 10715428 10715430 10928597 10928598 10928602 10928606 10715445 10715446 10928607 10928608 10928609 Jprints__ only-Job not complete) 17'7'- CJ~ç, 01/24/05 NO. 3318 SCANNED JUN 1 ? 20D5 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Log Description Color Date Blueline Prints CD 08/20/04 1 08/21/04 1 08/23/04 1 08/24/04 1 08/27/04 1 09/11/04 1 09/13/04 1 10/02/04 1 10/03/04 1 10/30/04 1 11/24/04 1 12/09/04 1 12/11/04 1 12/11/04 1 12/16/04 1 12/22/04 1 -' MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL ~~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: c)~f) Alaska Data & Consulting Services 2525 Gambell Street, Sui~OO /' AnChor.a...ge'AK~,950 Já38 1. ' ~J. . I ATTNCe. ~' / t \ / / /j Rece~d by:j~ ../f < VI ~ / II (/ //,/~? ALASKA OIL AND GAS CONSERVATION CO~I~IISSION TONY KNOWLES, GOVERNOR 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, APl 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, API 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 1) 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 ora coalbed reservoir these analysis include methane desorbtion measurements. 5) Sidewall core analysis and descriptions 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 Robe~ P. Crandall Senior Petroleum Geologist CC~ Robert Christenson Cammy Oechsli-Taylor Dan Seamount ALASKA OII., -'.ND GAS CONSERVATION ( .... "MMISSION - WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL: GAS: X SUSPENDED: ABANDONED: SERVICE: 2. Name of Operator 7. Permit Number Ocean Energy Resources Inc 99-66 3. Address ~_,%:..~~_ 8. APl Number P.O. Box 549, Newcastle, WY 82701 i~ ~_;~;;:?;';i'l'~'.~?::-'.:: 50- 009-20017 4. Location of well at surface :'. - - -~,t; ~, 9. Unit or Lease Name 793' FEL & 171' FSL Sec 15 T17N R2W ~ ::, ':i~~__~! Pioneer Unit 1702 At Top Producing Interval 793' FEL & 171' FSL Sec 15 T17N R2W · ~'~ .... ' .... ~--*' 15DD Jf ~ I · . At Total Depth .,,~f~.~_' _ 11. Field and Pool v i,, ~//V~L 793' FEL & 171' FSL Sec 15 T17N R2W ~ - ~ "'~. Tyonek 5. Elevation in feet (indicate KB. DF. etc.) J 6. Lease Designation and Serial No. KB 264'J ADL-374117 12. Date Spudded 13. Date T.D. Reached J 14. Date Comp.. Susp. or Aband. 15. Water Depth. if offshore J 16. No. of Completions I I 9/16/99 9/23/99 feet MSL 17' T°tal Depth (MD+TVD) 18' Plug Back Depth (MD+TVD) I 19' Directi°nal SurveY I 20' Depth where SSSV setMD 4228' TVD 4228' 4120' Yes: No: X NA feet MD 21. Thickness of PermafrostNA 22. Type Electric or Other Logs Run Segmented Bond Tool/Digital Acoustilog/Compensated z-densilog neutron log 23. CASING, LINER AND CEMENTING RECORD SE'I-FING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO'I-YOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 13 3/8" 68# J55 Surf 35' 17 1/2" 30 sx class "G" None 9 5/8" 36# J55 Surf 679' 12 1/4" 400 sx class "G" None 7" 23# CF-50 Surf 4212' 8 3/4" 730 sx class "G" None 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4052'-4056' 5SPF .45" hole 2 718" 2176' 4010' - 4014' 5SPF .45" hole 3916' - 3922' 5SPF .45" hole 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 3884' - 3890' 5SPF .45" hole DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 3748' - 3756' 5SPF .45" hole 4052-4056' 80 BBLs 2%KCL; .5%surfactant;1%EDTA 1948' - 1960 5SPF .45" hole 4010-4014 above amount used for all intervals 1420'- 1428' 5SPF .45" hole 3916-3922' 938'- 948' 5SPF .45" hole 3884-3890' 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) 12/12/1999I Swabbed, well currently shut in Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I 12/12/1999 24 TEST PERIOD => 0 0 0 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. SlTP 0PSI 24-HOUR RATE => 0 0 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Contiuation of Water Flush intervals 3748-3756' 1948-1960' 1420-1428' 938-948' .APR 2-."S L XKI Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. GEOLOGIC MARKERS ~MATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPT~ GOR, and time of each phase. Glacial Deposits Surf. Tyonek 372' ,. 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 report 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- ing 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". '..... April 6, 2000 Mr. I~,obe~l P, Crandall Senior Pelroleum Geologist 3001 Porcupine Drive Anclwrage, Ala.~ka 99501.3 192 Dour Mr, (;rand. Il: I am in receipt o£yotll' letler daled April 4. 2000, I am currently working on )'our requests. The one riling I would like to clarify is tidal eel has not com,n~nced tRice(ion operations into well 15 DA WDW, All of llle wells mentioned in you letter arc currently shut in until sometime in lhe spring when we will commence completion opurlttions. ] have been in contact with Chuck Wilson our Drilling Supervisor to collect the nddilion. I dam Ihal you arc requesting. A I,rgc portion office dala llltlSl COlll~ IFom our geological department nnd will come ou~ or Houston. Chuck is cu~ze,tly in fl~o process ofconmcting them ~o help us g~fi~cr fl~js inlbrmaion. I have made it clear to Mr. Wilson that tl~c Slat~ of Alaska is growing impatient and d~nt wc are overdue i, our requirements. Fie will relay this to ttouston and ask them to forward the requested items to the N~wcastle omcu so we cm~ make every eflbrt to see that )'ou receive all items that you have requested. I have in our files the daily drilling and operalions history, I will copy and forward these item.,; h.modiately as well as the ~wo lacking completion ri:pons and II~e logs on the BLT Ill and I SDA WDW. I apologize lbr all oflhe cont'usion and thank you For you cooperaIion. Sincert:ly, Oe~n Elderly, Irle, ti? ('~-ill{.ll..f [ )I'JVe t',l), I}t)l ?/'It9 Newc,~tle, Wyoming 82701 (307) 7~-40.~2 Fax: (.'Ill'/) 746.4045 ALASKA OIL AND GAS CONSERVATION CO~IISSION TONY KNOWLE$, 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 Energ?' Resources. Inc. #7 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 Energy Rcsourccs, Inc. (OER) received permits to drill the i 5 DA WDW: 14CC. and 15DD wells within the Pioneer Unit near Wasilla, Alaska. OER also received a permit to re-drill and recompletc the ARCO BLT # 1 well within this same unit. It is the Alaska Oil and Gas Conservation Commission's (AOGCC's) understanding that operations were conductcd in each of these 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 cach of these wells within 30 davs at~er 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 reports that OER has commenced injection operations into well 15DA WDW. According to our records. OER has not complied with these rcgulations, having only submitted incomplctc information on two wells. Your cooperation is required to bring OER into compliance with Alaska regulations. Your response to this letter will dctcnnine the actions we will undertake m 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 (Pemut 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 reports for production tests, drill stem tests or other formation tests (if conducted) Samples and laboratory analxtical results from conventional and sidewall cores (if obtained) Geochemical and formation fluid analyses (if obtained) Monthly Injection Report (Form 10-406) for thc months the well was used for disposal purposes. 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 tapc) 4. Data and reports for production tests, drill stem tests or other formation tests (if conducted) 5. Samples and laboratory analy/tical results from conventional and sidewall cores (if obtained) 6. Geochemical and formation fluid analyses (if obtained) Pioneer 1. . 3. 4. 5. o 7~ Unit 15DD (Permit to Drill Number 99-066): Geologic markers encountered (name. measured depth and truc vertical dcpth of each marker) Dailv drilling and operations history Sepia copies of all logs run Digital data and verification listings for all logs run (on diskette or tape) Data and reports for production tests, drill stem tests or other formation tests (if conducted) Samples and laboratory analy.'fical results from conventional and sidewall cores (if obtained) 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. Dailv drilling and opcrations history 4. Scpia 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 copy of the AOGCC's regulations is attached for your review. A prompt reply to this notification is cxpcctcd. If you have anv questions, please contact or Steve Davies or me at (907) 279-1433. Sincercly. Robert P. Crandall Senior Petroleum Geologist Attachment: Alaska Oil and Gas Conservation Commission Regulations. November 7. 1999 cc: Commissioner Seamounl March 13, 2000 State of Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: Pioneer Unit 1702 #15DD AP1 #009-20017-00 Permit # 99-66 Dear Madam or Sir: Enclosed for the subject well completion report are the following items: Form 10-407 (original and required copies) Logs ran on this well If you have any questions or need additional information please feel free to call me at 307-746-4052. Sincerely, Loretta Murphy Production Analyst RECEIVED Ocean Energy, Inc. #7 Cm~trel Drive P.O. Box 549 Newcastle, Wyornh~g 82701 (307) 746-4052 Fax: (307) 746-4045 STATE OF ALASKA ALASKA OIL ,,'~'"D GAS CONSERVATION Ct"'-'MISSION WELL CO,"vIP' ,--,,,-, OR RECOIVIPLETION RI.PORT AND LOG 1. Status of Well Classification of Service Well OIL: GAS: X SUSPENDED: ABANDONED: SERVICE: 2. Name of Operator 7. Permit Number Ocean Energy Resources Inc 99-66 3. Address 8. APl Number P.O. Box 549, Newcastle, WY 82701 50- 009-20017 4. Location of well at surface 793' FEL & 171' FSL Sec 15 T17N R2W At Top Producing Interval 793' FEL & 171' FSL Sec 15 T17N R2W At Total Depth 793' FEL & 171' FSL Sec 15 T17N R2W 5. Elevation in feet (indicate KB, DF, etc.) KB 264' 6. Lease Designation and Serial No. ADL-374117 9. Unit or Lease Name Pioneer Unit 1702 10. Well Number 15DD 11. Field and Pool Tyonek 15. Water Depth, if offshore 16. No. of Completions feet MSL ~t~¢._, 20. Depth where SSSV set I 21. Thickness of Permafrost NA feet MD I NA 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 9/16/99 9/23/99 I zl: z.i~ 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+I'VD) I 19. Directional Survey MD 4228' TVD 4228' 4120' I Yes: No: X 22. Type Electric or Other Logs Run Segmented Bond Tool/Digital Acoustilog/Compensated z-densilog neutron Icg 23. CASING, LINER AND CEMENTING RECORD CASING SIZE WT. PER FT. GRADE 13 3/8" 68# J55 Surf 9 5/8" 36# J55 Surf 7" 23# CF-50 Surf SE1 FING DEPTH MD TOP , 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) 4052' - 4056' 5SPF .45" hole 4010' - 4014' 5SPF .45" hole 3916' - 3922' 5SPF .45" hole 3884' - 3890' 5SPF .45" hole 3748' - 3756' 5SPF .45" hole 1948' - 1960' 5SPF .45" hole 1420' - 1428' 5SPF .45" hole 938'- 948' 5SPF .45" hole HOLE SIZE CEMENTING RECORD AMOUNT PULLED 17 1/2" 30 sx class "G" None 12 1/4" 400 sx class "G" None 8 3/4" 730 sx class "G" 25. TUBING RECORD None 3916-3922' 3884-389O' SIZE DEPTH SET (MD) PACKER SET (MD) 2 7/8" 2176' ,.~ 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) I AMOUNT & KIND OF MATERIAL USED 4052-4056' 1 80 BBLs 2%KCL; .5%surfactant;1%EDTA 4010-4014 above amount used for all intervals 27. PRODUCTION TEST Date First Production 12/12/1999 I Method of Operation (Flowing, gas lift, etc.) Swabbed, well currently shut in GAS-MCF 0 WATER-BBL 0 CHOKE SIZE I GAS-OIL RATIO PRODUCTION FOR TEST PERIOD => Date of Test 12/12/1999 Hours Tested 24 OIL-BBL 0 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. SITP 0PSI 24-HOUR RATE => 0 0 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Contiuation of WaterFlushintervals 3748-3756' 1948-1960' 1420-1428' 938-948' RECEIVED ~.!A~ 'i ~'2000 ,NaekaOit & Gas Cons. ~~n Anchorat~ Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. GEOLOGIC MARKERS .. MATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. ! i "~1. LIST OF ATTACHMENTS · 2. I hereby certify that the foregoing is true and correct to the best of my knowledge _.. Signe ' "~,~. (/~'/~?"~ ' ~"'/~'r- f Title ~_~ ~.¢'~"" O'~' I ' Date Form 10-407 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. 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 pedinent 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". RECEIVED Alaska Oil & Gas Cons. Core'ion DaiIy Report Wotl ID; Fionee~ Report No: 2 Ocean Energy Well Name: Pioneer Unit ~1722-15DC Report for 24:00 h~ 15-$ep-99 Ai:~ No~,' OND972D- $~*,~ 785 Rig Name; S~ud Date: '(6-Se~-98 D~ys: Sinca S~ud: On Lcca~io~ Measured D~pth; 0 ,:!eld: ,=;crsar T¢~I Well Co,ts: S2,k025 To~J Oaily Cost;s: Mu¢ Coet~: ~800 Total: Total Vertical Cep*,h: Hcfe Made: Average ROP: From To 0:00 3;00 Next: I~,~?~ a:35 ~ Co n~m c*,o~. ! O ~ervice; tv, we!¢ o~ c:2~,~c~r, mix ~pud muc scud wel; Mike M¢4~=cC geqnis Ack e,~,~n Operations Summary Co~o O~emtions Description 24,C0 ~ m~, -,a,",.,~eld o~ conductor, mix spud mud Last ~P Te~t: Other: 0 Total: '6 Daily Report WelllD: Pioneer 17021~DD Report No: 3 Ocean Energy Well Name: Pioneer Unit #1702-15DD Report for 24:00 hfs 16-Sep-89 Drill Pipe At Lot~ation: DP Size Joints 4,5 150 Weicjht 16.6 · First Aid: 0 Medical: Accident Description: Meetings/Drills Time Des~ril~fion L.~ BOP Test Sky Condition: cloudy Air Temperature: 45.0 Wind Sp~edl~3ir: ~ / F_NE deg F Grade Threacl E 4.SEH , Safe,.~ Information LOSt Time Accidents: rj Days Since LTA: 48 ~ i Crewnamatic Check Weather Visibility'. Bar. Pressure; Wind ~usts '. 15 $0 P~nted: ~,'34 f7.$~-~9 Page 3 Daily Report Well ID: l=loneer ~170215DD Report No: ,3 Ocean Energy Well Name: Pioneer Unit ~HTO2,'ISDD Report for 24:0Q h~s 16-Sep-99 ..... , ROP WOB Is, PM Torque Flow From To Av~j Max Aug Max AuG Max Aug Max AvL Max PSI 45 418 21.9 70.0 1 $ 20 120 200 33? 365 710 Comments; a~er ddliing bouiders for first ;001~ Then .-3moothe¢l out and much better Miscell~neous Drilling Parameters .... Hook Loads (lbs): -Off Bottom Rotate: Pick Up: Black Qff: :-'. Wear ~ushlng instal!ed Hole No Run Make Model D[am Made 1 1 STC 10MF 1~..~50 372 Depth From To AvL 4,5 418 2 L[thoiogy: 100% glaciei till Rig Name: CHi= ~nergy l~it Information .. ' R.O.P, W,O.B. R,P,M. Torque Mu~ Pump Hfs Av~I Max Avg Max Avg Max Avg Wt Flow Pre~s ~? 21.9 60.0 ~5 2~ 120 ?.00 9.~0 337 1500 Mad Log Infonmation. Gas Gas Drilling Pore ,Max at Depth Connect, Trip Exp, Pros RI~! !nformation RKI~ F._levation: 264.75 fi, Equipment Problems: Looa*Jon Condition cutup dowq, r~ceived m~tmr today, will ge[ installed ASAP. air ~ompressor, new one to arriue tomon'ow. wet $cree~ sizes: Top Middle Shaker No 1: 38 3.~ ,~haker No 2: 38 38 Shaker No 3: ~haker No 4: Solids Control Information ~o,-'1;om Equipment Usage: Hrs. 3~ Deaander: 18 Deaiiter~ Degasse~: Centrifuge No 1: Logistics Information Solids R~moval ,.~ollan Removal ~ull< Materials Cansumptlen and Inventory: Used This Re=aired This Repo~ Period RepoK Period Invenmq/ Barite: 0 0 0 Gels: 0 0 0 Cement.' ~ 0 0 Fu~l: 0 0 0 Fresh Water: O 0 0 Drill Water: 0 0 0 Truok/Boat Status: TO: ['~HCRSTLE ~. Daily Report Well ID: Pioneer 170215DD Report No: 3 Ocean Energy Well Name: Pioneer Unit #1702-18DD Report for 24:00 hrs 18-8ep-99 Ope~aior: Ocean Energy AFE N~s: DND972D. 54!8,785 Rig Name: CHP Energy spud Data: !6-8ep-9~ Days; Since SI=uti: 1 On Location: 3 Measured Depth: ~$18 Previous Re!3ort DepTh; 0 DH[I Hm= 17.0 Last Casing: Next: P~raonnel: Operator: 1 C~nmaotor, 10 Current Operations: Planned OperatJon~: Tooll~ushsr; Wellsite 8Upervisora,' From To Elated Code 0;00 4;Q0 4.00 RAJ 4:00 7:30 3.50 DRILL 7:30 8:00 0,50 REPR 8:0,:) 1 ~-'00 3.00 DRILL 11:O3 12:O0 1.00 TRPO 12:00 12:~0 0,50 TRP! 12:30 17:30 ~,00 DRILl. 17;30 18:C0 Q.SC SERV 18:00 21:30 3.5Q DRILL 2t'30 22:00 0.50 8URV 22:00 0:gO 2.02 DR',LL Field: Plone~ Unit To~al Well Costs: $$1 .~ 59 Total Daily Costs: $37,' 34 Mud Costs: $2,269 Total: $2,809 Total Vertical Depth: Hole Made: Average ROP: 15,~75 at 35 Last BOP Test: .Service: 5 Other: 0 Total: drig ~head at 5§~ ~ at 0400 Ars D.17-gg drlg shoed to TD mt 684-, pooh. tlh, elf and pooh to run Mlke. M~Naughton Denni-~ Ack,elan Operations Summary Operatior~ weld ~n conductcr& flow li~e spud 0400 hrs, 45 - 102 57 fi. 16,28 f'ph ~,1 pump down, fuel ~ine problems 102. - 1~.~ 4;3 fi. !4,;33 je~s nlugged, pooh e,hangea jets to 18's, tih 148 - 1 gi~ 5~ f-t, 10.8 ddllling boulders, ect~ like small boulders get above bit and try to stick us, Have to work lhru Ihnm. This is ~e same area h~l trouble in the other 2 wells also, One Jet plugged and other may be partially plugged lube & ~arvice dg 199 - 3?0 171 fi, 48.8 fph, got through boulder field wireline survey at :3:30 fi, ! 1/4 clog Comments souu ! 702-15DD ~ 0400 9-i ~9~J 418 24.6 18 Non-Prod had trouble with boulders 125- 200 ft, ~ame as in las[ wells. Once thraug;~ them al)goes preb'-y smonth. Density Vis Flit Cake PV YP 16-Sop 22:30 at Depth 22.20 9,C0 190 8',8 2 10 64 item Description Aqua Pac LV. ~ bag gel - i00# bag soda ash - 50# beg Mud Information % Gels Temp pH Solids Water Oll Sand Chloride 10s 10m ::]Om tn Out 9 4,2 95.8 0 3.2 gso 34 45 51 58.0 58.0 Mud Consumable Items 1 93 8 Cost Item Desm'ipticn Qty. Cost t7,5 engineer- I man 1 1,188 Gelex - 2# bag 8 128 120 P=ge 1 Dally Report Well ID: Pioneer'lT02'tSDD Report No: 4 · Operator: AFE Nos.' DND972D Rig Name: Spud Date: Days: Since Spud: Measurad De!3th: Previous Report Depf~h: Drill Hfs: Last Casing: Personnel: Operato~ Current O~-rations: Planned Operations: Toolpushen Welleite Su~,"visors: Ocean Energy Clip Energy · i 6;-sop.@9 2 On Location: 683 Next: Ocean Energy Well Name; Pioneer Unit #t?D2,.I~DD Report for 24:130 hfs '1 ?,Sop-99 Field: Pioneer Unit Total 'Well Coats: $97,B84 Total Daily Costs: $3~,725 Mud Costs: $2,300 Total: $5,10g Total Vertical Depth: 418 Helle Made: 265 Average ROD: 33.1 t 3.@75 at 35 Last BOP Test: 8em/ice: 6 Other: 0 Total: 18 weld on well heaal & prepare to test same do another t" top job While waiting far welJ head to cool, nu bop, test same Mike McNaughton Dannls Ac~<errnan From To Elapsed Code D.'00 8:00 &00 DRILL 8:00 8:30 0.~t0 SERV 8:;30 9:00 0.50 CIRC 9:00 10:00 1.00 TRPO '~o:00 10:30 0.50 TRPI 10;30 11 ;0C, 0.50 REAM ~1:00 11:30 0,50 TRPI ~i:30 12;¢0 0.50, CIRC 12;00 12:30 0.50 SIJRV 12:30 !3:00 0.50 ClRC 13:00 !4:30 1.50 TRPO 14:30 18:09 3.50 CASE '~8:00 10:3.3 '~.~o CIR¢ '/9:30 2_0:39 1,00 CMTP 20:;30 0.~O 3.5C WOC Density Vis Flit Cake PV '!7-@e.a 23:30 at Depth 683 8.60 37 ?,8 1 6 operatmn= Summary ........... Oi~rations Description 4~8 - ~3 265 ~ 33.13 ~h top of ~onek at 3~, 100 ff ~tgh t~ other ~ w~is lu~ & aeWi~e rig cir& cond p~h, couple of ba~a, wiped ~t ~ othe~vise ok Uh ~e 350 and took ~ re~ 339 - 3gg t~K a ¢~u;le k but no major problem t~h to bttm ~tho~ ~o~lsms, 1 ff fil~ ~r wirelike su~ey at 639, 0 d~ dt ~ wig problems, Id ~ 8" ~e ru & mn 15 j~s S 5/8 35~ J-5~ $TC csg, miner e~m drag 330. 400 ~o~ing major ~t w/400 ~, 2~ ~d, 737~ pps ~1~ fl~ke, 1 gps FP~L, ~.!5 15.~ p~, 4.96 wa~emo c~ to woc, peEorm 1" top job ~ 60 fl 5 bb~ w/3% ~cl, ~6.2 ppg ~ Mud Inflation . ,. % Gel~ Tamp YP pH S~i~WaterQilSand Chiedde ~Ds 10m 30m In Out 7 8.5 3.2 g6.8 0 I 800 ,t 8 10 56,0 60.0 , Mud Consumable Items . Item De~=dption Eiora~ - 50# bag geJ - I00'# bag Qty. Cost Item Oe~ription Qb/. Coat 1 43 De-~co CF - 25# bag 4 296 tg 242 engineer- 'I mar] 1 600 Page 1 Daily Report WellID: Pioneer'170215DD Report No'. 4 --. ROP From To Avg Max 418 683 33.1 60.0 Commerffm *.o@ of, tyonek 372 Hook Loads (lbs): . Dr/fling Parameters- WO& RPM Avg Max Avg Max .- Mis~ilaneous Drilling Parameters Off Bottom Rotate: Pfck Up: Ocean Energy Well Name; Pioneer Unit #1702.1aDD Rel~ort for 24:00 his ~?-Sep-99 Toque Plow Avg Max Avg MaX 355 7,30 Slack Off:. Wear Buahing Installed Hole NoRun Make Model Diem Made I 1 STC IOMF 12.25o 638 Rig Name; cHP Energy Bit Information, R.O,P. W,O.B. R.P.M, Torque Mud Pump Hfs Avg Max Avg Max Avg Max Avg Wt Flow Press 25 2,5.5 70.0 15 20 120 200 8.@0 365 730 Rig Information RKB Elevation: 284.75 ft Equipment Problems: · , . , First Aid: 0 Medical: 0 Accident Description: MeetingslDrilis Time Description Forgot to make note that CHP had rathole put in too dog off from original Icc design. Consequentially I'~d to move 2 dead men, cost 2.5 hfs of hole time to move them. safety Information ....... aeg F Sky Condition: Air Temperature: 55.0 Wind SpeedlDir: 351 Lc~t Time Aooidents: 0 Days Since LTA: 49 ~ Crownamafi~ Check Weather Visibility; ! 5 Bar. Prassure~ Wind Gus~: 45 6:04 19.~e1>.~'~ Page 2 Daily Report W~liID; Pioneer 17D215DD Report No: 5 -- ~ ........ .. Rig Infermafion Rig Name: CH, P Energy Equipment Problems: ~ pump not put together, rot head seals leaking badly Solids Control Infen'nation - Ocean Energy Well Name: Pioneer Unit #~1702.15DD Report for 24:00 hrs liI-Ssp.g9 ,. RKB F-Jevafion-' 2C;A, 78 ff Screen Sizes: Top Middle Bottom Eclt~ipment Shaker NO !: 5~ 5~ 50 D~ander= Sha~r No 2: 38 3~ D~ll~ S~a~r No 3: Deg~ 8ha~r No ~: Cen~ No 2; 20 ~ollds Remove! Solids Removai , Safe~y lnron, natlan Lost Time Accidents: First Aid: 0 Mecii~al; 0 A~cider~ Ch~scdptlon: Meafingslmrilis Time D~cdption ~ BOP Teat Sky Condiflmll cloudy, rain A~r Temperatua'e= 45,1~ ~/eg F Wind Speed/DIr: 101ENE 0 Days Since LTA: 50 ~'"' Crownematic Che-k Weather Vislbili(7: Bar. PresSure: W~nd GL~sts: Printed: ~-'04 ?~',.~ep-9~ Page 2 Daily Repo t Well ID: Pioneer 170215DD Report No: 5 operator= Ocean Energy AFE Nos: DND@72D- $4~8,7a5 Rig Name: CH/= Energy Spu~l Date: 16-$e~9 Days: Si~e Spurn 3 On Lo~on: 5 M~sumd Depth: ~3 Previous Repo~ De,h; ~3 DHIJ Hrs: ~ 0 Last C~l~g; ~.~5 Pemonnel: Ope~eto~ Current Operations: Planned O~mtiona= Toolpus~e~ WelJslte Sup~isars: From To EI;paed Code 0;O0 0:30 0.$0 woC 0:30 lB;00 7,50 N U~,JD 8:00 t2:00 4.00 ~iND 12:00 ~7:00 5.00 ~OPQT 't 7:00 17:30 0,50 PU/LI~ 17:30 18:00 0.50 BOPOT 18:00 20:00 2.{30 TRPI 20:00 21:30 1,50 OTHER 21:30 0:00 2,50 CMTD Ocean Energy Well Name: PiotJeer Unit #t?132-15DD Report for 24:00 bra 18.Sep.99 I=leld; Pioneer LJnit Total Well C~3sts-' $113.384 Tots! Dally Co.em: $52,225 Mud Cos'ts: ,e~00 Total: $3,40@ Total Vertical Hole lVtade= Average ReP: Density Vie Flit Cake PV 18-~e~ 15:00 at Depth 684. o 3 Item Description engineer- 1 man Hook Load~ (l13a); Next: 8,750at 4100 Last BOP Test: 17-Sop-g9 Contractor: 10 Service: 5 Other: 0 Total: change over to phpa mud dH ahead to care pt amUtld 1800 ft, take ~urveys every 300 unli[ see trend l~nnis Operations summary - Opemflori$ Description wait on c. mt we~c~ on 11" 3M x @ 818 sow well hsa¢/, test same, using hothead NU ROPE !er:,t hope 25~ tow, 2soo high, floor saftey valve fail, got new one, witnessed by John 8paulding, AOGCC Jd exce~s dp ins~ll wear hushing Pu nb#2, PDC $88EHPX w 8-~ 1% ~h w/dc to install rot heact & drive bushing tag cmt ~ 083, drlg cmt & float $@5 flair drlg very hard, probably :ub ~' turning. Mucl Information % Gele YP pH SeiZds Warm' Oil Sand Chloride 109 10m 30m 2 7.5 0,5 9g,8 0 0 · . Mud C~nsumable Items Qty. Cast Item Description 1 600 Miscellaneous Drilling Parameters Off Bottom Rotate: 52 Pick Up: Temp In Out 2000 No Run Make 2 I STC Model $SBEHPX Hole Dlam Made B.7~0 Hr.J Qty. Cost 53 81ack Off: 50 ~ Wear Bushing Installecl Rotate Hfs Trip Hra Casing.' 1,5 2.0 Bit Informatlan R,O,P. W.O.a, R,P.M. Torque Mud Pump Av{! Max Av9 Max Avg Max Avg Wt Flow Press , , ! Daily Report Well ID: Pio,eer 170215DD Report No: 6 --. ill -- Drill Pipe At Location: DP Size Jolnm Weight 4.5 150 16,6 First Al(I: O Medi=al: 0 Accident Description: Meetings/Drills Time Description BOP Test $k7 Condition: ~loudy, rain Air Temperature: 45,(~ oleg F Wlnd SpeedtDir: 10 / ENE Printecl: ~.'.5~ 20.$ep.99 Grade Thread E 4,SEH Safety Information Lost Time Accidents: Ocean Energy Well Name: Pioneer Unit #1702-15DD Repo~[ for24:00 hfs 1941ep.l~g 0 Days Since LTA: 51 ~ Crownamafl= Check ,__ Weather Visibility; Bar. Pressure: Wind Gusts; ,. 15 Page 3 Daily Report WellID: Pioneer17D215DD Report No: 6 --. - From To Hook Loads (lbs): Slow Clmulaflon Data: Pump 1', 32 _. Drilling Parameter~ ROP WOB RPM Avg Max Avg Max AVg Max 00.8 g0,0 10 20 110 ~40 Mlacellanaous Drilling Paramatern Off Bottom Rotan: ~ Plok Up; Ocean Energy Well Name: Pioneer Unit ~702-I~DD Report for 24:00 hr= 19.Sop-99 __ _ .. . _ Torque Flow Avg Max Avg Max PS1 365 .~ 10 Wear Buahing Installed spin psi Rotate Hfs Trip Hfs Casing: 2d.0 ~I~E Information_ Hole- R.O,P, W,O.B, NoRunMake Model Diem Made Hfs Avg Max Avg Max 2 I STC SBSEHPX 8.750 812 16 50.8 90.0 10 2D .... _ Mud Log Information From To Avg M~ at De~ ~83 ~12 30 ~01 t4,18 Li~ology/ 10% o~, 4D% s!t~, 50% ss Rig Name; CHI= Ene~' Equipment Pro,errs; ~ pump Location COndition we~ . , Screen sizes: 5he~r No 1: Shaker Ne 2: Shaker No 3: Shaker No ~: Rig infi3mlatlon R.P.M. Tom. us Mud Pump Avg Max Avg Wt Row Press 110 t40 8.~0 365 500 Gas Drilling Pore Connect. Trip Exp. Pres i i =- · ~KIB Elevation: 264.75 ft · Solids Control Information . _ __ _ Top Middle Bottom Equipment Usage~ 50 50 5025 Desander-' BO a0 Daa/Iter; IDegasaer; Certtrifuge No t: .....,, Logistics Information_ Bulk Mat~l'iala Consumption and Inventory: Used This Received This Report Period Report Period Invento~ Barite: 0 0 0 Gets: O 0 0 Cement: @ 0 0 Fuel: 0 0 0 Fres~ Wate~ 0 0 0 Drill Water: 0 O 0 Truck/Boat Stat~s: 24 Solid= Removal ~o~os ~emov~i Page 2 Daily Report Well ID: Pioneer '170215DD Report No: 6 __ Operator: Ocean Energy AFE Nos: DND972D-$418,78§ Rig Name; GNP Energy Spud Date: 10-Sap-9@ Days: Since Spud: 4 On La,arian: 6 I~e~$u~d Depth: 14~5 Previous Report Depth~ 683 Ddll Hm; 15.0 Ocean Energy Well Name: Pioneer Unit #1702,15DD Report for 24;00 hm t9,Sep-99 l Field: Pioneer Unit Total Well COat~: $157,444 Total Dally Cost~: $44,060 Mud Costa: $$,485 Total: $~,894 Total Verfi=al Depth: 1495 Hole Made: 012 Average RaP; 50.8 Last Casing: Peracnnel; Operator. Current Operations: Planned Operstior~: ToolpLISher: Weilsite Supervisors: From To Elapsed 0:00 2:30 2.50 9.625 at 679, Tested to 12.30 Next; 8.7§0 at 4100 Last BOP Test: 17-~ep-99 1 Conl~c~or.', 10 Service: 9 Other: 0 Total: 20 drtg ahead at t700 ~ geologist request tc~ time drt at 1800 ft at 1 mpfto look for core pt. drl aheaa[ to cOre pt around 1§$0, poc~h to core Brian Busby Dennis Ackerman · , Oper'at~ons Summary ,. Code CMTD 2:30 3:00 0.50 DRILL 3:oo 4:o0 1,00 CILOT 4:C0 7:00 3,00 DFCO 7;00 9:DO 2.00 DRILl. 9:00 9:30 0.50 SERV 9:30 14::30 ~-00 DRILL I4:30 15:00 0.50 SURV 15:0:3 20:00 ,5.00 DRILL 20:00 20:3O 0.50 SURV 20:3o 0:0o 3.50 DRILL Operations Description drlg float collar, ~mt 8, ~hoe, did 30 rain csg test above fc anti anther 6 rain test just above shoe to 900 psi fo drilled real hard but then cmt & shoe clrld OK 683- $94 11 fl, 22 fph perform FIT to 12.3 ppg EP,~A/ change out water to phpa mull,cleaned pits, used mud from test well ~ - 780 86 ft, 43 fph lube A service rig 780 - 1038 25,3 ft, $0.0 fPh wireJine slngie shot survey ~ 992, 2 dog 1033 · ~31B 283 ft, ,56.6 fi0h wiralJne single shot survey at 1285, 2 deg, !311~. M95 179 ft, 51.14 f'ph commmn4~ 0¢¢[~gi~t ~aqueSt to time dH at t mpf' at 1800 ft to correlate for ~or~ pt. Says I~ running just a fitt/e i~igh to 15DA well. .5 ppb phpa 4 ~pb klagard. Survey at 1600 ft, 3 dog , .. Mud Information .. , % Gels Ternp Density Vis Flit Cake PV YP pH ~olldsWateeOilSancl Chloride 40a ~Om agra In Out 19-Sep 23:30 at Depth 1474 9.00 ~.5 7.8 1 10 !0 9 4 96 0 I 4000 2 .5 $ 58.0 60.o Mud Conaumable Itema item DesorlptJon Caustic Snda - §~ Dog KlaOard - 55 gat Drum Qty. Cost item Desariptlon Qtl/. Cost 2 52 engineer. 1 man 1 §00 5 3,882 PoN Plus RD- 5Q:~ bag 7 1,003 Page Daiiy Report Well ID: Pioneerl7D2tSDD Report No: 7 ~ - Operator: AFl= No~: DND972D- $4!8.7~5 .Rig Name: ~y~: Sln~e ~pud: Porous Repa~ De,h: DHII ~st Casing: g.~25 at 679, Te=ted to ~ 2.~ Pemonnel: O~m~n I Castrator: Cutren~ O~erations; Plan~ o~mflons: Tool~she~ Brian Busby Weltslte Supe~leo~: Dennis A~er~n ,, Ocean Energy CNP Energy 5 On Location: 7 0 N~t,' iO Ocean Energy Well Name: Pioneer Unit Report for 24:00 hm 20.Sep.99 Field: Pioneer Unit Total Well Costs: $273,954 To~l Dally Casts; $11~,510 M~ Cos~s: $5,485 T~I: $~4,379 Total Vertical Depth: 1495 Hole Made: Average RaP: 8.750 at 4100 Last BOP Test: 17-~ep-g9 Servioe: 8 Other; O Total: 19 Daily Report Well ID: Pioneer I'/'02'15DD Report No: 7 Ocean Energy Well Name: Pioneer Unit #1?02-tSDD Report for 24:00 hfs 20.Sep.99 First Aid: O Medical: 0 Accident Description: Mee~ingsfDrills Tim~ Description I.~.: BOP Test - Safe~y Information Lost .Time Accidents: Days Slnoe I~TA: 52. -' Crownamaflc Cheak wea~ef Sky Condition: cloudy Air Temperature: 55.0 dog F Wind 8peed/Oir.' 0 ! Visibility; Bar. Pressure: Wind Gusts: Daily Report Weft iD: Pioneer 170215DD Report No; 7 Oparatc~r:. Ocean Energy ArE Hca: DNDg72D- S418,Ya5 Pig Name; CHP Energy Spucl Date: 16-$ep-99 Days: Since ~pud: § On Location: 7 Meaeure¢l Peptic: 1~47 Previous Report Depth: 1495 Drill Ha: t2-0 Last Casing'. Pemormeh Operator: Current Operations; Planned Operations: Tooil~usher: Wellsita Supervisors: 1, , , From Ta Elapsed 0'.Oo 3:D0 3.00 g.82~ at 679, Te~ted to 12,30 Next: 1 ConttaGtor: 113 pnoh wi aore #1, drld to 1958 ar~ s!opped, Id ohm #I, tth t~3 drl ahead ;, Brian Busby Dennis Ackcrman Operations $umm~ry - Code Operations Dea~rlplion DRILL 1495 - 1631 t,36 ft, 45.331fph Ocean Energy Well Name.' Pioneer Unit #1?02-1BDD Report for 24:00 hr,, 20.Sop-99 , 3:00 3:30 0.50 3:30 7:30 4,,00 7:30 11:30 4.00 ~. 1:30 !3:30 2.00 13:30 14:00 0.,50 14;00 14:30 0.50 14:30 15:00 0.50 '., .~:0015:30 0.50 15:33 IB:OO 0.50 15;00 18;C~0 18:00 2.1:30 3.50 21 :~0 0:00 2,50 chanoe ou[ rot SURV DRILL DRILL CIRC DRILL CIRC DRILL GIRD SURV TRPO REPR TRPI . Densi~ Vis Flit Cake PV YP 20-Sop 15:00 at 8.~0 4-5 7.4 Item Description engineer- I man RQP From To Avg Max Avg Max 1495 I947 37.7 70.0 10 20 Detriments; !ookiirlg for core pt Total: Last BOP Test: Other: 0 Total: Field: T~tal W~ll 0oat~: T~tai Daily Costs: Mud Costs: $743 TOtal Ve~cal Depth: H~le Made: A~erage ROP: &750 ~ 4100 Gels 1Os 10m 30m wireline single sho[[ survey~ at 1800, 3 de~ ~6@1. 1800 1~9 ~, 42.2§~ph 1800 - 1911, time d~ f~r g~ology, 111 fl, 27.75 fph cir ~ample for geolo~ 19~ 1 - ~942 31 fl, 60 fph,~ clr ~ample ns per geol~gy~ ~942. 1~47 5 fi, ~p es p~r geologi~ fro core pt~l ~r sampl~ for ge~y wlmiine single shot su~e~ at 1937, 3 1~ dog ~ for ~re ~I, Id ~b'~ $~ ~ange ou~ ro~ hea~, CH~'s locked up, in~all Grant pu core bb/th, insta~l mt ~ead Commenm ~ % pN Solids Wa~rOff?Sand Chlo~de 9,5 3,8 96.2 :~0 1 3800 6 g 10 Mud Consumable C~t I~m ~eacrtptlon 1 6D0 Poly ~lus RD - ~ bag 1 -- Drilli~g Pa~e~m ..... WOB R~M ToqUe Flow Avg ~M~ Avg ~x Avg Max 110 ~ 1~ 365 Pioneer Unit $276,712 $119,268 $9,837 1947 452 37.7 17.$ep.99 19 Non-Prod Temp In Out 56.0 62.0 Cost 14@ PSI 500 Page I Daily Report Well ID: Pioneer 170215DD Report No: 7 Ocean Energy Well Name: Pioneer Unit #1702,15DD Report for 24:00 hm 20,Sep-99 .. L- Miscellaneous Drilling Parameters Hook Loads (lbs)'. Off ~,ottom Rotate; 73 Pi~k Up: Slow Clmulafion Data: Pump 1: 32 spin 150 psi spin psi No Rum Make Model 2 1 STC 888EHPX 3 I BAKER ARC-~5 77 Slack Off= 65 .'~ Wear Bushing Installed spin psi Rotate Hfs Trip Hfs Casing: ~2.0 4.0 Hoje Diem Made ~.750 t2~4 6.25O Bit Information R.O.P. W,O. EI. R,P,M. Torque Mud Pump Hm Avg Ma=[ Avg Max Avg Max Avg Wt Flow Press 2~ 45.~ O0,0 16 20 120 140 8.90 365 500 __ . Muci Lo12 Information Depth Gas Fr~m To Max a[ Depth 886 945 Gas DrllIInl] Pore Connect, Exp, Pres 45 Avl] Trip 1495 1947 g 190 Lithoiogy: 5% coal. 75% slier, 20% as Rig II, formation Rig Name: CHP Energy RKB Elevation: 264.75 Equipment Pmblsms; mt head =iezed up again, ~ange out to ~rant shorty on lob for core bbl i.~stalling #2 @ump tc~lay ~olid$ C~ntrol Infom~at[on Solids Removal Solids Removal Screen Sizes: Top Middle Eottorn EquipmemUsage: Shaker No 1: 50 50 2.5 Desancler: Shaker No 2: 110 1 t 0 Desiitar; Shaker No 3: Deg=sser: Shaker No 4: Cen~fuge No ~.' Centrifuge No 2: I I ~isfl~ Information Bulk Materials Censure priori and Inventory; Barim: Gels= Cement; Fuel: Fresh Water: Drill Water: U~e:t This Resolved ]'him R. port Period Rei~.,t Period 0 Ttu=VJBeat Etatua: Drill Pipe At Location: DP S[2e Joints 4.~ 100 Weight 16,~ Grade Thread E 4.§EH Page2 Dally Report WelllD: PioneeriTO215DD Report No; 8 - ,-- · .... i ii . Operator: AFE Nos: DND972D - $418,78~ Rig Name: spud Date: Days: ~inGe 81arid: Measured Del=th: Ocean Energy Previot~ Report Depth: Drill Hr'a: !-~at Casing: ClIP Energy 16-Se~-BB $ On Lc=cation: 8 2625 t947 15,0 g.62~ at 879, Tasted to 12.30 Next: Ocean Energy Well Name: Pioneer Unit #1702-t5DD Report for 24:00 hfs 2'1,8ep.99 i r-~_~ F., laid: pioneer unit Total wail costs: $327,771 Total Daily C~oste: ~ud Costs: $8,834 Total: $18,471 Total Vertical Depth: 2825 v Ole Made: 678 elrel~e ROP: 45.2 8.75(~ at4100 Last BOP Test: 17.Sep-99 Personnel: Ol~mtor: Cu~ent Operations: Planned Operations: Toalpu~her: Weilalte 8upervl~om: Ill From To E]apted Code 0:O0 0:30 u.,50 TRPl 0:30 1 :OQ 0.50 CIRC 1:00 2:30 !.50 CORE 2:30 5:00 2.50 TRPO $,.00 7:30 2.~0 TRPI 7:30 8:00 0.50 REAM 8:00 12:30 4,.~0 DRILL, 12:30 13:00 0,20 SERV t3:00 ?,1:30 8,50 DRILL 2t:30 22:00 0.50 SURV 7..~ :00 O:O0 2.00 DRILL I Confl'aeter: 11 Servmce: 8 Other: 0 Total: 20 drlg ahead at 281~ ~ 0400 hrs ~-gg. ddg ah~d to ~ Mi~ McNeughton Dennis A~e~n O~emtiona 8umma~ ....... Opera. ns ~c~pflon ~ ~nstaii mt he~d spa~ Obi c~ ~s Up & ~ ~I 1947- I~S ~1 [ 7.33 ~h appo~ 7 ~ coal ~re p~ w/=re ~, ~d & re=over same, 100% re~ve~, appmx 6.5 fl H i; ~u bit ~2 tr, s~ a~ 30 & ~o ~ mas ~ 1/~ =ere ~ole 194~ - ~ gsa - 2~9 141 ~, 31,3~ fph, sm~ to ~d d~l-x lube & seewl~ fig 2~ - 2~75 3~ [ ~,2~; fph wimUne ~le shot su~y ~ 2~3, 4 dog 2475. 2625 1~ ~ 7~ ~h . C~men~) __ , ;Il going well toclay, PHorto ?.300 had high enough torque t~at oouidn't put over 12-~.15 wob, ~is is prob~ly due to the mom agrossive ~dc bit ~4" cu~s). Was able la increa~ ~b ~er ~ ~ :help~ mp considerably. Also at ~at time added more dM-x, ~id be tha~ Lh~ also ~de a di~re~e. mi dril-x is t .S%, d~nata~, glvlr~ b~er The wey ~ings Itek here, we wi~ pmbab~ be Ceady ~ ~e ~ S~, But will nat be able to move until Mon. As ~erm~ ioad= ~ ~ve cver~ weekend, U~ be sh~ do~r 1 dev. Mud lnfo~aflon -' % ~i Gels Temp pH SolidsW~rO~Sa~ Chloride ~Os ~0m a0m In Out Density ~m Flit Calve PV YP 21-.Sop 01:80 at Dep(h 2780 8.95 44 I~,2 1 S 23 Item Oeac, ription Aqu~ Pa= LV - 50~ bag engineer- 1 men i 8,5 4,2. @5,8 !iO 0.2S 3800 9 11 14 64,0 64.0 Mud Consumab,? Items .......... Qt'y, Co~ l~m ~cdp~on O~, Cost ~ ~m ma~pr~-SSg~Drum 2 ~,~3 F Dally Report We, ID: FloneerlT(1216DD Report No: ti Drii X? - 55 Gat Drum 1958 Comments: j. D~lllng Pa~me~ ..... WOB Ocean Energy Well Name: Pioneer Unit #1702-15DD Report for 24:00 hm 21-8ep-69 To Avg Max Avg Max Avg Max 2625 45.2 1 OD.0 ~ 125 increase w=b in to 20 - 25 k at about 2:]00 fi, before that time running 10 -15 clue to h~gh table torque ,, . R/flm:eilaneoU'.~ Drilling Parameters Hook Loads (lbs): Off Bottom Rotate: 85 Plak Slow Ciroulatl~n Data: Pump ~; 32 spm ~e~ ;si spin ........... Bit Hole Diem Made 6.250 11 8.75~ 657 Ne Run .Make M~el 3 1 B~K~R ARC-325 2 2 STC $88EHPX i _.. Tarque Flow Avg IVlax Avg Max 31~5 880 Depth Fr~m 1947 IL._ . i I: 94 Slack Off: 85 ~ Wear Bushing Installed spm psi Rotate Hm Trip Nm Casing: 49.0 9.0 R,O,F. !:, W.O.B. R.P.M. Torque Mu= Pump Hra Avg Max i~vg Max Avg Max Avg WI: Flew Press 1.5 7~ 4~.0 ii 4 ~ 75 80 B.90 225 475 '5 ~.5 t~.0 ~17 25 110 125 8,90 365 850 .Mud Log I~a~on ......... ., Gas Drilling Po~ M~ at Beth Conne=[ Trip ~p. 868 lb52 45 !90 264,75 ft To Avg 1~58 3 I.ithology: core #1, 05% cOal, 3,~% elbst, recover 7 ft ~ coal 18,55 262.q 1 q 5 1593 2~214 125 Umology: 5% c~al, 60% sltst 35% ~ !i ,. .... Rig Infomlatl6n ..... PJg Name: CHP Energy J, RKB Elevation: Equipment Problems: flL?. pump ba~k :ogether end aveilbiaj!for use Location Condition wet il ......... Selid$: Control Info~afi,~n _ Screen Size~: Top Middle Shaker No I: 50 50 Shaker Ne 2: 110 110 Shaker No 3: Shal<er No 4: I~oel:orn Equll~a~t Usage: Hrs. ~' Oeaander: ;[5 Centrifuge No i: Ce~trf~ge No 2: '.~ 20 Solids Re~oval Sallds Removal Page 2 Daily Report Well ID; Pionaer 1702t,;,DD Rep=rt No: 8 i i1. i ;. II ,. Logistics nfmTn~tion Bulk Ma~rials Consumption and In~Mo~= Barite: Gets: Cment; Fuel; Fresh Water: Drill Water; Truck/Boat Status: Ocean Energy Well Name: Pioneer Unit #17112,15DD Report for 24'.00 hm 21-Sep.99 ..-- Used This Received Tttls Repm-t~ PeHect Report Period Ir~ventory 0 0 0 0 0 0 0 0 o 0 0 0 0 0 0 0 0 0 Drill Pipe At DP Size Joints Well;Iht 4.5 150 16.6 i . __ Flint Aid: 0 Medic~h A¢oldent Description: Meetings/Drills Time Description BOP Test Sky Condition: cloudy- r~in Air Temperature: 45,0 d~g F Wlnd Speed/DIr: 10 / E Grade Thread E 4.SEH Safety Information L~st Time ACcleents: 0 Days Since L'i'A: ~ Cmwnamatic Che~k Weather _. . vls[l~ility: Bar. Preeaure; Wind Guat~: F~'ntec~; 5:3'1 2~-,,?,ep-~ Pa~e 3 Daily Report Weir rD: Pioneer t?02~5DD Report No: 6 Fimt Aid.' 0 Medical: Aceidsnt Description: Ocean Energy Well Name: Pioneer Unit #t?02,15DD Report for 24:00 hrs 22,Sep-99 _ Safety lnfarmafion ~: Lest Time Aec!dents; 0 Days Since LTA: ,54 Moefin~s,~Drilis '~rne Description ~ BOP Test Sky Condition: c~=udy Air Temperatura: 40,0 deg F Wind $peed/Dir:. 20, / sast ~ Crowrmmafic Check Weather Vlslbility: Bar. Pressure: Wind Gust~: Daily Report WeIIID: Pioneer I?02t$DD Report No: 9 -'~ __ mi i Operator:. Ocean Energy AFE Nos: DNDg72C - $354,325, DND.q72D ~ $418, Rig Nmme: CHP E,,~r~ Spud Data: Day~: Since Spud; 7 On Location; 9 Measured Depl~: 3756 Previoum Report Depth: 2~25 Drill H~: Ocean Energy Well Name; Pioneer Unit #17D2.15DD Repo~ for 24:00 hrs 22-Sep-99 i!i Field: Pioneer Unit Total Well Coete: $357,804 Total Dally Casts: $2g,533 Mud C,~te; $5,gSB Total: $24,429 Total Vertical Depth: 3756 Hole Made,' 1131 Average ROI=: 53.9 Last Casing: I~eraonnei: Operator: Curt'ant Operations: Planned Operations: Toolpushar.' Wellslte Supervleor~: Fr~m To Elapsed 0:00 7:30 7.50 7:30 8;00 0.50 8:00 8:39 0.50 ~:30 9:09 0.50 9:00 10:O0 ! .00 10:00 10:30 0.50 9.b"25 at679, Tested to 12.30 Next: ~ 8,750 at 4,100 Contrau'~r: '~ 1 Service.' 8 O~ller: 0 cirlg ahead at 39~, g~ogi~t r~ going to give TD ASAP drlg ahead t~ 'rD, ~=~ trip to DC, pa~3h roi' logs Mike M~Nau~hton ' Dennis Ackerman · · opemtion~summa~y Code Operations Description [:;,AILL 2625 - 2999 374 ,~; 4~.8 fph SURV wirelike single shot'Survey at 2995, mis~un, no picture DRILL 2999- 3031 32 ft, 64 fph sURV wimllne single s.hotsurvey at 3027, misrun, took picture but ~uldn't see it ~Jear enough DRILL 3031. 3125 94 ft, g~ fph SURV wire!Ina single ~hot!i~urvey at 3~20, 6 deg. Found that developer had to bs kept warm. 10:~0 12:30 2.00 12:30 13:00 0.50 13:00 14:3~ 1 14:30 ~ ~:00 050 15:C~0 22;30 7.50 22;30 23:00 0.50 23:~0 0:00 1.00 pnp; .25 ppb, ddlx-t 1,5%, kta~ard 4 ppi: DRILL 3125 - 3252 127 ft;; 83.5 fph SERV lube & ;evi¢~ rig DRILL 3252 - ~ g4 fi, 62.~ f~h SERV ct~ange s~r sm~ns, h~ h~ in 2 panels. DRILL 33~6 - ~92 3~ fl,~.13 ~h ':. 3UEV ~n~e shot ~ret~ Suwey m 3660, 7 DEI~ 36~2. 3755 63 ~ ~ ~h :. ~d Info~fion Cake PV YP ~H ~lids Wa~rOII ~d 1! 21 9 ~.5 93.~ 0 2,25 37~B 13 , M~ ~naumable Items ~. C~ l~m D~e~en 5 875 ~ CF - 2~ bag Density VI~ Flit 22.~ep 01 :do at Depth 3755 9,20 $0 9.4 1 Item D~cription A~a Puc LV - 5~ beg Dr~l XT - 55 Gal ~um KlaGard - 55 gal Drum XCD. 2~ ~g Last BOP Teat: 17.$ep-99 Total: 20 3 2~329 PDtassium Chloride. 50~ bag Pi~y Plus RD - 50# bag Gals Tamp 10m 3Om In O~ 15 t8 67.0 67,0 City, Cost 6 3~0 1 600 27 ~1 I 14~ _11111 Page 1 Daily Report Weir ID; Pioneer 17021SDD Report No: 9 , c_ , From To 2~.5 ~758 ,Hook Loads {lbs): Slow Circulation Data: Pump I: 33 spin Ocean Energy Weft Name: Pioneer Unit #1702.15DD Report for 24:00 hm 22-Sep.99 i mi_ Drillin~i Parameters ROP WOB RPM Avg Max Avg Max Avg Max 53.8 gO.0 20 25 140 150 .,_ Miscellaneous Dl'iiling Parametera Off Bottom Rotate: 90 Pick Up: 240 psi spin psi Torque Avg Max Flow Avg Max 365 95 Slack Off: Hole No Run Make Moclei Diem Made 2 2 STC SeaEHPX tL750 1708 Oep~ From To A~ 2525 3756 PSt Sit Information R.O.P. W.O.B. Hra Avg Max Avg NLax Avg Max Avg 37' 48J~ 90.0 20 25 140 15~ R,P,NL Torque Mud Pump Wt Flow Press 9.20 365 990 . Mud Log information Gas Gas M~x at Depth ConneoL t64~ 3080 100 LithoIogy: 5% COAL, 45% 8LST, 45% SS, 5% CONGL, RKB Elevation: Rig Name: CHP Energy Drilling Pore Trip Exp. Pres IR. Itl' Information Solids Control Info~mation ._ IVIidclle Bottom Equipment Usage: 50 25 Desander. 110 Oesilten Degasser. ::antrifuge No 1: Carmtfuge No 2: Legiatlr. s Information , Top _t Screen Sizes: Shaker No 'I,: Shaker No 2: Shaker No 3; Shaker No 4: Bulk Materials Consumption and Inventory: Used This Received This Report Period Report Pedod Inventory Barite: 0 0 0 Gels: 0 0 O cement: 0 o 0 Fuel: 0 0 0 Fi'esh Water: 0 0 0 Drill Water: 0 0 o Tm=k/Boat Status: 2~,75 ft 24 Solids Removal ~olids Removal Drill Pipe At LocatJon: DP Size Join~ Weight Grade Thread 4.~ ! 50 16,6 E 4,SEH Daily Report WellID: Pioneer 1702!5DD Report Not 10 II 11_ Drill Pipe At DP Size JaJnts 4.5 Weight 16,6 II ii I FimtAid: 0 Medi~nl: Acclclent Description: Maetlngs/Drlil~ Time Dascription ~ ~P Teat. Sky Condition: Air Temperature; Wind P~ted: ~:32 §5.0 clog F 5! Ocean Energy Well Name: Pioneer Unit ~H?02.15DD Report for 24:00 hm 23-Sop-99 Grade E ii 4.SEN Safe~y inf~natlon ~ Crownarnafl= Check Weather 0 Days Since LTA: 55 VI~II~ilI'Ly: Bar, Pressure: Wind Guata: 2O Page 3 Daily Report WeliID: PioneerlT021SDD Report No: 10 Ocean Energy Well Name: Pioneer Unit #1702.t5DD Report for 24:0o hm 23,.sap.ss Poiy Plus .RD - .50# bag XCD - 25# beg ROP From To Avg Max 37~ 4228 37,0 75.0 cornmerrte; l'D Wall Hook Loads (lbs)= No Run Make 2 2 STC Model S88EHP;~ Depth From 37~6 Uthology: , . RIg Name: CHP Energy S=reen Sizes: Shaker No I: Shaker No 2: Shaker No 3: Shaker No 4: 2 ;~87 Potassium Chloride - 50# bag 0 O Drilling Pammetem WCB RPM Torque Avg Max Avg Ma~ Avg Maz 20 25 135 150 ........ Nllaaellaneoua Drilling Pa~meters Cfi Bobom Ro~: 1134 Pick Up: -27 -361 Flow Avg Max PSI 386 980 alack Off.' lQ0 Wear BUahlng Installed Rotate Hrs Trip Hm Ca~ing: 82,5 43,0 Bit Inf~rmatlen ..... Hole R.O.P. W,O,g, R.P.M. Dias Made Hn~ Avg Max Avg Max Avg Max Avg 8.7~ ~70 48,5 ~,B gO,O 20 25 130 1~0 Mud ~g Info.arVn . . . Gas To Avg Maz ~ ~ Con~ THp 4228 gO 11!00 3~0 100 5% ~al, 80% ss. 16% sitar RIg Info~tl~ R~ Elevation: Solids Ca~ol Info~en To~ Middle Baff~ Equicor U~ge= Ha. 80 50 25 O~ander', t10 1~0 ~il~r; Dega~er: C~fu~ No 1: Cen~ Ne 2; Logi~ti~ Inr~rma~Jon,. Bulk Matedale conaumptl=n anti lnventor~: Torque Mucl Pump Wt Flow Press gOO 38~ goo Drilling Pore Exp. Pres Used This Recalvad This Repo~ Perjecl Report Period Invento~ Barite: o 0 0 Gels: 0 Cement: 0 o 0 Fuel: 0 0 0 Fresh Water: 0 0 0 DHI! Water: 0 0 0 Truok/Boat 2E4,75 ft 24 Solids Removal Solids Removal Pe~e 2 Daily Report Well ID: Pi~neer~_~?02'rSDD Report NO: 10 Ogerator: Ocean Energy AFE No~; DNDg72D-$418,785 Rig Name: CHP Energy Spud D. ate: 16-~sp-g9 Days: Since Spud: 8 On Location: 10 Measured Dep~: 4228 Previous Rel~ort Depth'. 3756 Drill Hn~: 12.2 La~ Casing: @,625 at 679, Te~e~ to 12,3'3 Next: Personnel.' Operator: Current Operations: Planned Operations: Teolpushe~ Wellsite Supervisor: Ocean Energy Wall Name: Pioneer Unit #1702-15DD Report far 24:00 hfs 23-asp-99 , - Field: Pioneer Unit Total WoJl Costs: $382,505 Total Daily Coef~: $26,201 MUd Co~ts~ $5,176 Total: $29,605 Total Vat, cai Depth: 422@ H~le Made: 472 Average RaP: 37.8 8.750 at 4100 Last BOP Test: 17-$ep-99 1 Contractor: 11 Servi~e; 7 Other: 0 Total: lagging w/Baker Atlas, log #1 resistivity finish io~glng wl density nawtron, no sidewalls cores planneci, rib, cir, Id dp, run csg Mike McNaughton D~nnis A~kerman Qperations Summary Fram To Elapsed Code 0:00 0:30 0.50 CIRC 0:30 3.~0 2.50 DRILL 3:00 4.00 1,00 RE[aR 4:00 9:30 5,50 DRILL g:30 t0:00 0.50 CIRC 10:00 13:30 3,50 DRILL 13:30 14:00 0,50 SERV 14:00 15:00 1.00 DRILL 15:00 16:00 1.CD SURV' 16:00 17:00 1.C.~ GiRO 17:00 19:;30 2.50 TRPO 19:30 22:00 2.50 'r'RPI 22:00 23:30 1.50 ClEO Operations De,c;ription oh' samples as per geolo~i~l 375~ - 3913 157 tt, 62,8 fpll dlrve line bolts loose, tighten ~eme 3913 - 4071 158 ft. 28.72 ~h, rough drlg clr sample as per geologist, want to catch desorbtJon sample on last coal 4r071 ' 4~ 97 126 ft, :36 fpM lube & service dg 4t97 - 422a 31 fi, 31 fph singie shot wireline ~urvey a~ 4197 - 7 3/4 dog cir &c~nd short trip to dc, ~e 3306-.:~.?.1,35 k op, 2300-2480 40 k ~p, w~rk thru a couple times then OK tlh t~ bttm w/o pet;lees clr, quite a bit of coal on bttms up .,-.,,k, 4.,., I,-,,.,~, h ~e+ .,.,.,, ,,., ..,.o, ~.,.. e bobble et 2400 Co.mania ..... ph.~a .4 ~pb, ~-x ti, 1,5%, klaga~d ~, ppb. 8it Is Dret~ wel~ gone. Will have exa~ data later. Mud Information % Gels $olid.~ Water Oil 5and Chloride ~Oe 10m 30m 6,5 93,~ 0 2.?.:i 3700 5 12 22 Mud Consumable [tams Non-Prod Tern p In Ou{ 65,0 65.0 Item Description Aqua Pac LV - 5~ 0ag 7 Desto CF · 25# bag 14 engineer- 1 man Cos[ Item De~dpfion Qb', 1,225 Csustta Soda- 5C~ bag 1 722 Ddl XT- 85 Gal Drum 2 600 KlaGard - 88 gal Drum 1 Cost 26 1 ,~01 776 Page Daily Report Well ID: Pioneer l?n215DD Report No: 11 Ocean Energy Well Name: Plon~r Unit #t 702-'1~DD Report for 24:00 hrs 24-Sep.99 BUlk Materials Consumption ~nd Inventory.' I.=gta~i=s lnfm~on Usecl This Reseived This Report Period Report Perlee[ Inventory Barite: 0 0 0 Gel, s: Cement: Fuel: 0 0 . Fresh Water: 0 0 0 Drill Water- 0 0 0 TrucI,Jaoat s~tus: Drill Pipe At Lc~aflorl; DP Size Joints Weight 4,5 150 16.6 First Aid; 0 Medical: 0 Accident OescHption; Meetings/Drills Time De~=riptlon ~ BC)P T~t Sky Condition: pc Air *l'empera~ure; 35.0 deg F Wind 9pee~l/Dir] 0 / Grade Thread E 4,SEH Safe[7 Information Lost Time ~=l~lems: Days Since LTA: ~ Crownamatic Check Weather Visibility; Bar. I=ms~ure; Wind Gusts; P,'l~tea' 6:25 25-$e/~-9g Page 2 Daily Report Well ID; Pioneer 1702t,~DD Report No: tl Ocean Energy Well Name-' Pioneer Unit #t702-It~DD Report for 24:00 hfs 24-8ep.99 Operator: Ocean Energy AFE Nas: DND872C-$;354,325, DND972D - $418, Rig Name: CHP Energy Spud Date: 1~-Sep-99 Days: 8inca SpUd: 9 On Location: 1; Measured Depth: 422.8 Previous Rapar~ Depth: 4228 Drill Hm: 0 Last C~ing: Personnel: Operant. Current Operations; Planned Operations: Toolpur~er: Weiisite Superv!~or~: .~. From To Elapmad Code 0:(30 3:313 3,50 TRPO .3:30 6:30 3,00 ;M. OG 6:30 11:D0 4.50 WLOG 1! :el0 11:30 0,50 BQPQT 1~:30 !4:00 14;00 15:30 Field: Total Well Costs: Total Dally Costs: Mud Cc~ts: $1,185 Total Vertical Dap:Il: Hale Macle; Average ROP: 15;30 16:30 16:30 18;30 18:30 0;00 Total: Pioneer Unit $481,340 Sa4,a3s $30,7gD couldn't get wear bushing pull~ in ~ru spacer spool or rot head. W~I pull when pu sta~k to set slips, .... l'~d ln~rm~fl~m .... 4228 9,625 ~ ~7~, Tested to !2.30 Next= 8.750 at 4100 Last BOP Test: 17-$ep-gg I ~n~r: tl 5e~i~; 7 Other: O ?o~l; 19 r~ning 7" ~, tin,ih 7" csg, ~ m~ ba~ tom ~ yld, cmt flint stage, cir 4 hrs. cmt ne~nd s~ge Mi~ M~aug~on Dennis ,~ker~n o~mfi~s Summa~ ,. O~m~o~ De~ri~on pooh D' I~e, ~nor bobble at g400 ~log w[ Baker A~as, mn ~1 ,HDIL-D~R 4215 - 0 ~UN ~ ZDL~N.GR-C~L 41~ ~ to pull ~ buahl~, ~dn~ ~et ~ller through mt h~d o~ soa~r spooJ 2.50 TRPI pu b~ ~ab at ~ and 6o 1.50 R~AM ream ~30 - 2475 23~0 to 2370 was under gauge, didn't real~ see ~.00 TE~I ~ :Ih to b~, ~ problems 2.00 CIRC tlr& ~n: 5,~ PUJ~ Id dp, ~, b~ak k~ly C~men~ , -. Gels YP pH SolidsWater Oil Sand Chloride 10a 10m 30m 11 g ~.§ ¢-~.B 0 2 3700 ., Mud Con~umal31e Items Qty, Cost Item Dee~Hpfl~n 1 000 XCD-~&bag ?,lla~l~n~ Drilling Pamme~ Off Boflom R~m: Pick U~ Temp In Out 4 12 25 60.0 60,0 3 585 i Slack Off;, [] Wear Bushing In.~talled Pa3tate Nm T~p Hrs Casing: 91,5 6Z.O Denal~ Vis Flit Cake PV 24-8ep 03:00 at Depth 422a 9.20 47 8,4 t 7 ir.l.. Item Description engineer. 1 man Loads (lbs); Rig Name: .. CHP Energy , Rig Information RKB Elevation: 264,75 It i . Page 1 Daily Report Well ID: Pioneer 17021-5DD Report No: Aid: 0 Medi=al: A==ident Description; Meafingr./Drills Time Dascription ~ BC}P Test 5ky C=ndlUon: ri=n, haii, sunny Air Temperature: 35,0 dog c. Wlnd Speed/Olr: / Safety Infermation Lost Time Accidents: Ocean Energy Well Name: Pioneer Unit ~702-15DD Report for 24:t~0 hrs 2S. Sep.99 _ · _ . ,,! 0 Days Since LTA: 57 Crownamatic Check Visibility: B~'. Pressure: Wind Gusts: Daily Report Well ID: Pioneer 1702t5DD Report No: 12 Ocean Energy Well Name: Pioneer Unit #1702-141DD Report far 24:00 hfs 25,Sep.69 Operator; Ocean Energy AFE Nos: DND972C- $354,325 Ri; Name: CHP Energy' Spud Date: 16-~ep-99 Days: Since Spud: ~ On Location: '12 Measured Oe~h~ 4228 Previous Report Depth: 422.8 Drill Hrs; 0 Last Casing: 9.625 at 679, TeSted tO 12,30 Next: Currant Operations: nd, clean mud tanks Planned Operations: ncl, wait on BLT loc Tooipusher: Mike MoNaughten Wellsite Supervisors; Dennis A~t(erfllan From To Elapsed Code 0:00 1:30 1.50 PUtLD Field; Pioneer Unit Total Well Costs: $$30.624 Total Daily Coats: $63,284 Mud Costs: $9o9 Total: $31,699 Total Verlical Deptll: Hc~e Made: Average ROP: 8.750 at 41 O0 Last BOP Test: Operations Summary Operafione Description Id dp 422B 17-Sep-9~ 1:30 2:30 1.00 BOPOT 2:30 12:00 S.§0 CAgE 12:00 !5:30 3,~ CRCF 15:3Q 17:3Q 2.00 CMTP 17:30 21:30 4.00 CRCF 2!;30 ?2:30 1.00 CfVrrP 22:30 0'.00 1.50 NU/ND Install 7" c, sg rams run 103 its, 7" 2~ CF-50 LTC 4, DV ~ollar at 2109 ~ir & et mud back to 7 yld, 34 vis, Ii.9 wt ¢~lt f~mt stage w/37g sx"G~ w/1% FL-82, ,~o A~2, 2 gl~s FP-6L wt 15.8 yld 1.153 4.92 water/ex, pumped 77 bbl~ ~,mt drop beep, open DVC w 500 psi, eir out 20 bbls MC$-4 spacer and 20 bbls mud contaminated ca~t 2nd stage cat job, IB~I~ lead ,G" wi 2~ A-2, .4% CD-32, ,8% CACL, 1 gpa ~'1;-6L, 11.95 gpo water, 12.5 plug, 2.10 yld 2~ bi:Is slurrt, Tail- 209 sx "(3" W/1% FL-B2, 3.% A-2, 2 ghs FP~CL, 4.92 gp$ water, 15.8 p~, 1.153 yld. 40,5 =bis sturry. Diepleee w/8&§ bbls wat~, dr out 10 bbis spacer and less t~n 5 ~!s cmt. nd bope, set slips w//75,000 lbs .... Comments i, cut mud baCk t~ 8.9 6 yld for cmt jobs first stage went well, appears a good cmt job, had addltiona1400 psi ~n differential and cai to cir out 40 bbla end ~hat la what we g~t back, Density Vis Flit Cage Fv YP pH 2~-,sep 2..3:3c3 at Depth 422.8 8.90 14,4. I 4 6 g Mud Information % Ge le Tem p Solids W=ter Oil Sand Chloride 10s 10m 30m In Out Item Deasription Desco CF; - 25# bag 4.2. c25.8 0 2, 3700 3 4 8 8g,0 8g.0 Mucl C~nsumable If~rns 6 310 engln~r- 1 man 1 600 Rig Infusion ,. R~ Elevat~n: 2~.75 ff Rig Name.' CHP Energy ~,iaska Oil.& gas ~ OOa31~g ~ehorage Page Daily Report Well ID: Pioneer 170215DD Report No: 13 Ocean Energy Well Name: Pioneer Unit ~1702-15DD Report for 24:00 hrs 26~ep-99 Operatc~f: O~ean Energy AFE Nos: DND!~72C - $354,$25 Rig Name: CHP E~e~y Spud D~a= 1 Days; Since Spud: 9 On Location: 13 ~asu~ De~: 4~8 P~io~ ~po~ Dep~= 4228 DHII He: ~=t Ca~ing: 7.000 a~ 4212 Personnel: Operato~ Current Operatlone: Planned Operations: Taelpu~her: Weli~ite Superviaem: From To Elapsed 0:00 3:30 $,50 :3:30 8:00 4.50 Con, rector: 11 Service: released at 0800 hfs Field= Pioneer Unit Total Well Cos'cs: $$45.g49 Total Dally Oost~: 516.025 Mud cost~; $800 Total: $~2,299 Total Vertical Depth: 4228 Hole Made: Average ROP: Last BOPTest: 17.Sop.g9 7 Other;, 0 Total: 19 Mike M¢~aught~rl Dennis Ackerman ,, Ope?atlons Summary Code Op~ralJons DNcription ~OPOT ng "eieasecl at 080o mrs 8-20-g~ nd, instal! csg slips w/75,000 lbs, cut off 7" & weld on clean mud rani(s, start rd procedures., dg relaesed at ~800 hrs 8-2e-9@ Comment~ 20.'47 2S..,Se~.99 Page COMPLETION SUMMARY PIONEER UNIT 1702-15DD 10/01/99 10/02/99 10/03/99 10/04/99 10/05/99 10/06/99 10/07/99 10/08/99 10/09/99 MIRU CH&P RIG 19. NU AND TEST BOPE AND MANIFOLD. REPORT TEST RESULTS TO AOGCC. PU 6 1/8" BIT AND DC'S. RIH W/TBG. DRILL OUT DV TOOL AT 2109'. WASH TO PBTD ~ 4102'. CIRCULATE HOLE CLEAN. POOH W/ TBG. LD BIT AND DC"S. RU ATLAS WIRELINE. RAN CBL W/O PSI FROM PBTD TO 3500'. REPEAT FROM PBTD TO SURFACE W/ 800 PSI. FORWARD CBL TO AOGCC. PU 6 1/8" BIT AND CASING SCRAPER. RIH TO 4120'. CIRCULATE HOLE W/2% KCL WATER. SWAB FL TO 1300'. POOH W/TBG. RU ATLAS WIRELINE. PERFORATE W/4 ½" HSC 5 JSPF 43 GRAM CHARGES .45" PERFORATIONS AS FOLLOWS: 4052'56', 4010-14', 3916-22', 3884-90' & 3748-56'. NO BLOW AFTER PERFORATING. PU BAKER RETRIEVAMATIC PACKER AND TIH. SET PACKER AT 3999'. TEST ANNULUS TO 500PSI. RU TO SWAB LOWER ZONES. SWAB TO X NIPPLE. RECOVERED 15 BBL. MADE 1 RUN/HR FOR 2 HRS W/NO FLUID RECOVERY. SITP 0 PSI. MADE 1 SWAB RUN W/NO FLUID ENTRY OR . RECOVERY. SITP 0 PSI. MADE 1 SWAB RUN W/NO FLUID ENTRY OR RECOVERY. RU BJ SERVICES TO BD PERFS 4052-56 & 4010-14' W/50 BBL 2% KCL WATER + .5% NONIONIC SURFACTANT + 1% EDTA AND 40 BALL SEALERS. FLUSHED W/30 BBL 2% KCL WATER. FINAL INJECTION RATE 3.8 BPM 3850 PSI. ISIP 3180 PSI 15 MIN 2650 PSI. BD AND SWAB BACK BD FLUID. RECOVERED 58 BBL OF 80 BBL LOAD. SITP 25 PSI. SWAB. IFL 1900' RECOVERED 18 BBL FLUD FOR DAY. 76 BBL OF 80 BBL LOAD. SITP 0 PSI. RU SWAB. IFL 3800'. RECOVERED 1 BBL FLUD. RELEASE PACKER AND POOH W/TBG. PU BAKER RBP AND RETRIEVAMATIC PACKER AND TIH. SET RBP AT 3976'. PACKER AT 3722'. FILL AND TEST ANNULUS. SWAB TO X NIPPLE AT 3722'. RECOVERED 20 BBL FLUD. SITP 0 PSI RU SWAB. IFL 3700' NO FLUID ENTRY. RU BJ SERVICES TO BD PERFS 3916-22, 3884-90' & 3748-56' W/50 BBL 2O/o KCL WATER + .5O/o NONIONIC SURFACTANT + 1% EDTA AND 100 BALL SEALERS. FLUSH W/25 BBL 2O/o KCL WATER. FINAL RATE 3.9 BPM ~ 3724 PSI. ISIP 3280 PSI. 15 MIN 2552 PSI. BD AND SWAB BACK 41 BBL OF 80 BBL LOAD FLUID. 10/10/99 SITP 100 PSI. RU SWAB IFL 2500'. RECOVERED 15 BBL FLUID. 56 BBL OF 80 BBL LOAD. RELEASE PACKER RETRIEVE RBP POOH AND LD PKR AND RBP. TIH W/XN NIPPLE AND 131 JTS TBG. 10/11/00 ND BOPE. LAND TBG AT 4060'. NU WELLHEAD. RDMO CH&P RIG 19. 11/15/99 MIRU CH&P RIG 19. NU AND TEST BOPE. RU SWAB. SITP/CP 0 PSI. [FL AT SURFACE. SWAB FL TO 500'. 11/16/99 POOH W/TBG. RU ATLAS WIRELINE. PERFORATE W/4 ½" HSC 5 JSPF 43 GRAM CHARGES .45" PERFS 1948-60'. NO APPARENT BLOW AFTER PERFORATING. PU BAKER MODEL G RBP ANF TIH. SET RBP AT 2019'. POOH AND PU BAKER FULLBORE PACKER. TIH AND SET PACKER AT 1904'. 11/17/99 SITP 0 PSI. RU SWAB [FL 700'. SWAB TO XNNIPPLE AT 1904'. RECOVERED 7 BBL FLUD. 11/18/99 SITP 0 PSI. RU SWAB [FL 1100' SWAB TO XN NIPPLE. RECOVERED 5 BBL FLUID. RU BJ SERVICES TO BD PERFS 1948- 60' W/50 BBL 2% KCL WATER + .5% NONIONIC SURFACTANT + 1% EDTA AND 75 BALL SEALERS. FLUSH W/20 BBL 2% KCL WATER. FINAL RATE 5.7 BPM ~ 2090 PSI. ISIP 1505 PSI 15 MIN 1230 PSI. BD AND SWAB BACK BD FLUD. RECOVERED 29 BBL OF 70 BBL LOAD. 11/19/99 SITP 200 PSI. FLAMMABLE GAS TO SURFACE. RU SWAB. IFL 200'. SWAB TO XN NIPPLE AT 1904' AND CONTINUE W/ 1RUN/HR FOR 8 HRS. FFL 1450' FINAL RATE 2 BPH SLIGHTLY GAS CUT FLUID. 28 BBL FLUD RECOVERED FOR DAY. 57 BBL OF 70 BBL LOAD RECOVERED. 12/01/99 SITP 20 PSI. FL AT SURFACE. RELEASE PACKER AND POOH W/ TBG. 12/02/99 TII-I W/TBG AND RETRIEVE RBP POOH. RU ATLAS WIRELINE. PERFORATE W/4 1/2" HSC 5 JSPF 43 GRAM CHARGES .45" PERFS 1420-28'. WL SET RBP AT 1500'. TIH W/FULLBORE PACKER AND SET AT 1368' 12/03/99 SITP 0 PSI RU SWAB IFL 350'. SWAB TO XN NIPPLE AT 1368' RECOVERED 5 BBL FLUID. RU BJ SERVICES TO BD PERFS 1420- 28' W/50 BBL 2%KCL WATER + .5% NONIONIC SURFACTANT + 1% EDTA. FLUSH W/30 BBL 2% KCL WATER. FINAL RATE 6 BPM 1830 PSI. ISIP 830 PSI 15 MINUTE 720 PSI. SWAB BACK 16 BBL OF 80 BBL LOAD. 12/04/99 SITP 180 PSI. FL AT SURFACE. SWAB TO XN NIPPLE AT 1368' AND MADE 1 RUN/HR FOR 8 HRS. FINAL RATE ¼ BPH. RECOVERED 10 BBL FLUID. 26 BBL OF 80 BBL TOTAL LOAD RECOVERED. 12/05/99 SITP 0 PSI. RU SWAB. IFL 900'. SWAB DOWN. RECOVERED 3 BBL FLUID. 29 OF 80 BBL LOAD RECOVERED. RELEASE PACKER AND RETRIEVE RBP. POOH W/TBG. 12/06/99 SICP 0 PSI. RU ATLAS WIRELINE. PERFORATE W/4 ½" HSC 5 JSPF 43 GRAM CHARGES .45" PERFS 938-48'. WL SET RBP AT 1000'. RIH W/FULLBORE PACKER AND SET AT 906'. SWAB TO XN NIPPLE AT 906'. RECOVERED 2 BBL FLUID. 12/07/99 SITP 0 PSI. RU SWAB NO FLUID ENTRY. RU BJ SERVICES TO BD PERFS 938-48' W/40 BBL 20/o KCL WATER + .5o/0 NONIONIC SURFACTANT + 1% EDTA. FLUSH W/25 BBL 2O/o KCL WATER. FINAL RATE 5 BPM ~ 1060 PSI. ISIP 563 PSI 15 MIN 513 PSI. SWAB BACK 9 BBL OF 65 BBL LOAD. FINAL RATE ½ BPH. 12/08/99 SITP 0 PSI. RU SWAB IFL 600'. RU BJ SERVICES TO BD PERFS 938-48' W/500 GAL 7 ½% HCL ACID + .2% INHIBITOR + .5% SURFACTANT + 1% EDTA. ACID ON PERFS AT 3 BPM 830 PSI. FLUSHED W/18 BBL 2% KCL WATER. FINAL RATE 3 BPM ~ 790 PSI. BD AND SWAB BACK 9 BBL OF 30 BBL LOAD. 12/09/99 SITP 0 PSI. NO GAS TO SURFACE. RU SWAB IFL 500'. SWAB TO XN NIPPLE AT 906'. MADE 1 RUN/HR FOR 8 HRS. RECOVERED 6 BBL FLUID. FINAL RATE 1/4 BPH. 15 BBL OF 30 BBL LOAD RECOVERED. 12/10/99 SITP 0 PSI. RU SWAB IFL 500'. RELEASE PACKER AND RETRIEVE RBP ~ 1000'. POOH AND LD TOOLS. RIH W/2.205" ID XN NIPPLE AND 70 JTS TBG. ND BOPE AND LAND TBG AT 2176'. NU WELLHEAD. RDMO CH&P RIG 19. 01/29/00 SECURE WELLHEAD W/LOCKS AND CHAINS. INSTALL WELLHEAD SHELTER. SI WAIT ON FRAC EQUIPMENT. OCEAN ENERGY RESOURCES, INC. DAILY RIG REPORT Well: PIONEER UNIT #1702-15DD Perfs: Location: SEC 15 T17N R2W TD/PBTD: Date: 10/5/99 KB/G L Work Done on: 10/4/99 Others: Present Operation: SWAB TEST ZONE I N/A 4120' 264'/253' Operations Planned: PREP TO BREAK DOWN PERFS Time . From To DAILY OPERATIONS 1 O/4/99 RU BAKER ATLAS WIRELINE EQUIPMENT TAG FL AT 1580'. !PERFORATE W/4 1/2" ALPHA JET CASING GUNS 5 SPF AS FOLLOWS: 4052'-4056' 20 HOLES 32 GRAM CHARGES .45" PERFORATIONS 4010' - 4014' 20 HOLES 3916'- 3922' 30 HOLES 3884'- 3890' 30 HOLES 3748'- 3756' 40 HOLES NO BLOW OR FLUID ENTRY. RD BAKER ATLAS. PU BAKER OIL TOOLS 7" RETRIEVAMATIC PACKER AND 2.205" XN NIPPLE RIH W/129 JTS TBG. SET PACKER AT 3999'. FILL ANNULUS AND TEST TO 500 PSI RU TO SWAB. FL 1500'. SWAB TO X NIPPLE.RECOVERED 15 BBL WATER SD 1 HR. MADE 1 RUN W/NO FLUID RECOVERY. SWIFN. COSTS PREVIOUS DAILY CUMULATIVE Rig $18,000 $4,500 $22,500 Su pe rvision - $3,000 $750 $3,750 Rentals $1,200 $400 $1,600 Roustabouts $1,200 $0 $1,200 Tra n s po rtation $4,750 $0 $4,750 Cement, Acid, Frac. $0 $0 Perforating, Logging $3,376 $4,767 $8,143 Subsurface Pumps $0 Rods, Scrapers $500 $0 $500 Tubing, Subs, SN $0 TAC, Packer, Repair $3,490 $3,490 Others $0 Location $750! $0 $750 Misc. $0 Electrical $0 Water $1,000 $450 $1,450 Contingency $3,378 $1,436 $4,813 TOTAL $37,154 $15,793 $52,946 OCEAN ENERGY RESOURCES, INC. DAILY RIG REPORT Well: PIONEER UNIT #1702-15DD Perfs: Location: SEC 15 T17N R2W TD/PBTD: Date: 10~6~99 KB/G L Work Done on: 10~5~99 Others: Present Operation: SWAB TEST ZONE 1 N/A 4120' 264'/253' Operations Planned: PREP TO BREAK DOWN PERFS Time From To DAILY OPERATIONS 10~5~99 ITP 0 PSI RU TO SWAB. MADE I RUN TO XN NIPPLE @ 4000' FL AT 3975' NO FLUID RECOVERY SWIFN. COSTS PREVIOUS DAILY CUMULATIVE Rig $22,500 $1,125 $23,625 Supervision $3,750 $750 $4,500 Rentals $1,600 $400 $2,000 Roustabouts $1,200 $0 $1,200 Transportation $4,750 $0 $4,750 Cement, Acid, Frac. $0 $0 Perforating, Logging $8,143~ $0 $8,143 Subsurface Pumps $0 Rods, Scrapers $500 $0 $500 Tubing, Subs, SN $0 TAC, Packer, Repair $3,490 $0 $3,490 Others $0 Location $750 $0 $750 Misc. $0 Electrical $0 Water $1,450 $450 $1,900 Contingency $4,813 $273 $5,086 TOTAL $52,946 $2,998 $55,944 OCEAN ENERGY RESOURCES, INC. DALLY RIG REPORT Well: PIONEER UNIT #1702-15DD Perfs: N/A Location: SEC 15 T17N R2W TD/PBTD: 4120' Date: 10/7/99 KB/G L 264'/253' Work Done on' 10/6/99 Others: PKR (~ 4000' Present Operation: SWAB BACK BREAKDOWN FLUID Operations Planned: Time From To DAILY OPERATIONS 1 O/6/99 ITP 0 PSI RU TO SWAB. MADE 1 RUN TO XN NIPPLE ~ 4000' FL AT 3975' NO FLUID RECOVERY RU BJ SERVICES TO BREAKDOWN PERFS 4052-56' & 4010-14' BD FLUID 2% KCL WATER W/.5% DOWELL F40 NONIONIC SURFACTANT AND ' 1% DOWELL U40 EDTA CHELATING AGENT. ~LOAD HOLE W/23 BBL BD FLUID PRESSURE ANNULUS TO 1000 PSI. ESTABLISH INJECTION AT 1/4 BPM 2815 PSI. INCREASE RATE TO 3 BPM ~ 3640 PSI PUMPED 27 ADDITIONAL BBL BD FLUID W/40 1.3 SP.GR. BALL SEALERS START 30 BBL 2% KCL FLUSH INCREASED RATE TO 4 BPM AT 3720 PSI. PRESSURE INCREASED TO 4000 PSI 3.6BPM W/20 BALLS ON PERFS FINAL INJECTION 3.75 BPM @ 3960 PSI ISlP 3180 PSI 5 MIN 2846 PSI 10 MIN 2711 PSI 15 MIN 2630 PSI. SI TBG RDMO BJ SERVICES TOTAL LOAD 80 BBL RU TO FLOW BACK BLED TO 0 PSI IN 2 MINUTES. RU SWAB IFL @ SURFACE. SWABBED TO XN NIPPLE ~ 4000' IN 11 RUNS. RECOVERED 58 BBL FLUID SWIFN. COSTS PREVIOUS DAILY CUMULATIVE Rig $23,625 $4,500 $28,125 Su pe rvisio n $4,500 $750 $5,250 Rentals $2,000 $600 $2,600 Roustabouts $1,200 $0 $1,200 Transportation $4,750 $0 $4,759 Cement, Acid, Frac. $3,331 $3,331 Perforating, Logging $8,143 $0 $8,143 Subsurface Pumps $0 Rods, Scrapers $500 $0 $500 Tubing, Subs, SN $0 TAC, Packer, Repair $3,490 $0 $3,490 Others $0 Location $750 $0 $750 Misc. $0 Electrical $0 Water $1,900 $650 $2,550 Contingency $5,086 $983 $6,069 TOTAL $55,944 $10,814 $66,758 OCEAN ENERGY DALLY RIG REPORT Well: PIONEER UNIT #1702-15DD Perfs: Location: SEC 15 T17N R2W TD/PBTD: Date: 10/8/99 KB/G L Work Done on: 10/7/99 Others: Present Operation: SWAB BACK BREAKDOWN FLUID N/A 4120' 264'/253' PKR @ 4000' PERFS: 4052-56' Operations Planned: BD UPPER ZONE 1 PERFS 4010-14' Time From To DAILY OPERATIONS 10/6/99 ITP 25 PSI BLED DOWN TBG RU TO SWAB. IFL 1900' SWAB TO XN NIPPLE IN 3 RUNS. RECOVERED 13 BBL FLUID MADE 1 RUN/2 HRS FOR 10 HRS RECOVERED 4.6 BBL ADDITIONAL FLUID. 17.7 BBL FOR DAY SDFN. WELL OPEN TO TANK TOTAL LOAD 80 BBL LOAD RECOVERED 75.7 BBL LOAD REMAINING 4.3 BBL DELIVERED 2 SAMPLES TO CT&E LAB IN ANCHORAGE SAMPLE #1 BASE FLUID 2% KCL + .5% F40 + 1% U42 SAMPLE #2 SWAB RECOVERY FROM 11:00AM SWAB RUN. COSTS PREVIOUS DAILY CUMULATIVE Rig $28,125 $4,500 $32,625 Supervision $5,250 $750 $6,000 Rentals $2,600 $600 $3,200 Rousta bouts $1,200 $0 $1,200i Tran s po rtatio n $4,750 $0 $4,750~ Cement, Acid, Frac. $3,331 $0 $3,331 Perforating, Logging $8,143 $0 $8,143 Subsurface Pumps $0 Rods, Scrapers $500 $0 $500 Tubing, Subs, SN $0 TAC, Packer, Repair $3,490 $0 $3,490 Others $0 Location $750 $0 $750 Misc. $0 Electrical $0 Water $2,550 $0 $2,550 Contingency $6,069 $585 $6,654 TOTAL $66,758 $6,435 $73,193 OCEAN ENERGY RESOURCES, INC. PIONEER UNIT #1702-15DD Location: SEC 15 T17N R2W Date: 10/9/99 10/8/99 BD UPPER ZONE 1PERFS Work Done on: Present Operation: Perfs: TD/PBTD: KB/GL Others: DALLY RIG REPORT N/A 4120' 264'/253' PKR (~ 3722' PERFS: 3916-22' Operations Planned: SWAB BACK BD FLUID 3884-90' 3748-56' Time From To DAILY OPERATIONS 10/8/99 WELL OPEN TO TANK OVERNIGHT 0 PSI RU TO SWAB. IFL 3800' SWAB TO XN NIPPLE IN I RUN. RECOVERED 1 BBL FLUID RELEASE PACKER AND POOH W/TBG. PU MODEL G RBP W/BALL CATCHER AND RETRIEVAMATIC PACKER ~RIH W/TBG. SET RBP AT 3986' SET PACKER AT 3722'. FILL ANNULUS W/KCL WATER AND TEST TO 500 PSI RU TO SWAB. SWAB TO XN NIPPLE IN 3 RUNS. RECOVERED 20 BBL FLUID WAIT I HR AND MADE 1 ADDITIONAL RUN W/NO RECOVERY. SWIFN. COSTS PREVIOUS DAILY CUMULATIVE Rig $32,625 $4,500 $37,125 S u pervision $6,000 $750 $6,750 Rentals $3,200 $600 $3,800 Roustabouts $1,200 $0 $1,200 Tra n s portatio n $4,750 $0 $4,750 Cement, Acid, Frac. $3,331 $0 $3,331 Perforating, Logging $8,1431 $0 $8,143 Subsurface Pumps $0 Rods, Scrapers $500: $0 $500 Tubing, Subs, SN $0 TAC, Packer, Repair $3,490~ $3,885 $7,375 Others $0 Location $750! $0 $750 Misc. $0 Electrical $0 Water $2,550 $0 $2,550 Contingency $6,654 $974 $7,627 TOTAL $73,193 $10,709 $83,901 OCEAN ENERGY RESOURCES, INC. PIONEER UNIT #1702-15DD Location: SEC 15 T17N R2W 10/10/99 10/9/99 Date: Work Done on: Present Operation: SWAB BACK BD FLUID Perfs: TD/PBTD: KB/GL Others: DALLY RIG REPORT N/A 4120' 264'/253' PKR (~ 3722' PERFS: 3916-22' Operations Planned: 3884-90' 3748-56' Time From To DAILY OPERATIONS 10/9/99 ,, SlTP 0 PSI RU TO SWAB. IFL 3700' . SWAB TO XN NIPPLE IN 1 RUN. NO FLUID RECOVERED RU BJ SERVICES TO BD UPPER ZONE 1 PERFS FILL TBG W/20 BBL 2% KCL WATER W/.5% F40 SURFACTANT AND 1% U42 EDTA. PRESSURE ANNULUS TO 1000 PSI. ESTABLISH INJECTION AT 2450 PSI 2.5 BPM. ;PUMPED 30 BBL BD FLUID W/100 1.3 SP.GR. BALL SEALERS. iFLUSH W/25 BBL 2% KCL WATER. INCREASE RATE TO 4.5 BPM @ 3790 PSI BALLS ON PERFS PRESSURE VARIED FROM 4.2 (i~ 3880 TO 3.9 (~ 3790 FINAL PUMP IN PRESSURE 3.9 BPM (~ 3724 PSI. ISIP 3280 PSI 5 MIN 2801 PSI 10 MIN 2650 PSI 15 MIN 2552 PSI RDMO BJ SERVICES. BD TBG IN 2 MINUTES RU TO SWAB. SWAB TO XN NIPPLE IN 9 RUNS. RECOVERED 41 BBL FLUID. SWIFN. COSTS PREVIOUS DAILY CUMULATIVE Rig $37,125 $3,775 $40,900 S u pe rvis ion $6,750 $750 $7,500 Rentals $3,800 $600 $4,400 '15,o u stabouts $1,200 $0 $1,200 _Tra n s po rtation $4,750 $0 $4,7F1(~ Cement, Acid, Frac. $3,331 $2,609 $5,940 Perforating, Logging $8,143 $0 $8,143 Subsurface Pumps $0 Rods, Scrapers $500 $0 $500 Tubing, Subs, SN $0 TAC, Packer, Repair $7,375 $0 $7,375 Others $0 Location $750 $0 $750 Misc. $0 Electrical $0 Water $2,550 $510 $3,060 Contingency $7,627 $824 $8,452 TOTAL $83,901 $9,068 $92,970 OCEAN ENERGY DALLY RIG REPORT Location: Date: Work Done on: Present Operation: PIONEER UNIT #1702-15DD Perfs: N/A SEC 15 T17N R2W TD/PBTD: 4120' 10/11/99 KB/GL 264'/253' 10/10/99 Others: PKR (~ 3722' LAND TBG AND MO RIG PERFS: 3916-22' Operations Planned: 3884-90' 3748-56' Time From To DAILY OPERATIONS 10/10~99 SlTP 100 PSI RU TO SWAB. IFL 2500' SWAB TO XN NIPPLE IN 2 RUNS. 11 BBL FLUID RECOVERED MADE 1 RUN/HR FOR 4 HRS. RECOVERED 4 BBL ADDITIONAL FLUID. 56 BBL OF 75 BBL LOAD RECOVERED. RELEASE PACKER. RIH AND RETRIEVE RBP. POOH W/TBG. LD PKR AND RBP RIH W/2.205" ID XN NIPPLE AND 131 JTS 2 7/8 J-55 EUE TBG. SWlFN. COSTS PREVIOUS DALLY CUMULATIVE Rig $40,900 $3,775 $44,675 Supervision $7,500 $750 $8,250 Rentals $4,400 $600 $5,000 Roustabouts $1,200 $0 $1,200 Transportation $4,750 $0 $4.750 Cement, Acid, Frac. $5,940 $0 $5,940 Perforating, Logging $8,143 $0 $8,143 Subsurface Pumps $0 Rods, Scrapers $500 $0 $500 Tubing, Subs, SN $0 TAC, Packer, Repair $7,375 $0 $7,375 Others $0 Location $750 $0 $750 Misc. $0 Electrical $0 Water $3,060 $0 $3,060: Contingency $8,452 $513 $8,964 TOTAL $92,970 $5,6381 $98,607 OCEAN ENERGY Well: PIONEER UNIT #1702-15DD Location: SEC 15 T17N R2W Date: 10/12/99 Work Done on: 10/11/99 Present Operation: SI WAIT ON STIMULATION DESIGN Perfs: TD/PBTD: KB/GL Others: Perfs: DALLY RIG REPORT N/A 4120' 264'/253' PKR @ 3722' 4052-56' 3916-22' Operations Planned: 4010-14' 3884-90' 3748-56' Time From To DAILY OPERATIONS 10/11/99 SlTP/CP 0 PSI ND BOPE LAND TBG AT 4060' W/131 JTS TBG IN HOLE NU WELLHEAD $1 WELL RDMO CH&P RIG 19 COSTS PREVIOUS DAILY CUMULATIVE Rig $44,675 $2,250 $46,925 Supervision $8,250 $750 $9,000 Rentals $5,000 $0 $5,000~ Roustabouts $1,200 $0 $1,2004 Transportation $4,750 $0 $4,7501 Cement, Acid, Frac. $5,940 $0 $5,940 Perforating, Logging $8,143 $0 $8,143 Subsurface Pumps $0 Rods, Scrapers $500 $0 $500 Tubing, Subs, SN $0 TAC, Packer, Repair $7,375 $0 $7,375 Others $0 Location $750 $0 $750 Misc. $0 Electrical $0 Water $3,060 $0 $3,060 '~ontingency $8,964 $300 $9,264, TOTAL $98,607 $3,300 $101,9071 OCEAN ENERGY Well: PIONEER UNIT #1702-15DD Location: SEC 15 T17N R2W Date: 11/16/99 Work Done on: 11/15/99 Present Operation: PERFORATE 1948-60' Perfs: TD/PBTD: KB/GL Others: Perfs: DAILY RIG REPORT N/A 4120' 264'/253' PKR (~ 3722' 4052-56' 3916-22' Operations Planned: SWAB TEST 4010-14' 3884-90' 3748-56' Time From To DAILY OPERATIONS 11/13- 11/15 .,, MIRU CH&P RIG 19 SITP/CP 0 PSI ND WELLHEAD NU BOPE SWAB FL TO 500' -. SWIFN ,-- ,.. COSTS PREVIOUS DAILY CUMULATIVE 'l~,ig $46,925 $7,750 $54,675 ..Supervision $9,000 $1,500 $10,500 Rentals $5,000 $1,200 $6,200 Roustabouts $1,200 $0 $1,200 i-ra n sportation $4,750 $4,834 $9,5841 Cement, Acid, Frac. $5,940 $0 $5,940; Perforatin9, Loggin9 $8,143 $0 $8,143i Subsurface Pumps $0 Rods, Scrapers $500 $0 $500 .Tubing, Subs, SN $0 TAC, Packer, Repair $7,3751 $0 $7,375 Others $0 Location $750! $0 $750 Misc. $0 '~Electrical $0 Water $3,060 $1,040 $4,100 [Contingency $9,264 $1,632 $10,897 TOTAL $101,907 $17,956 $119,864 OCEAN ENERGY .Esou.c s, INC. PIONEER UNIT #1702-15DD Location: SEC 15 T17N R2W Date: 11/17/99 Work Done on: 11/16/99 Present Operation: SWAB TEST 1948-60' Perfs: TD/PBTD: KB/GL Others: Perfs: DALLY RIG REPORT N/A 4120' 264'/253' PKR @ 3722' 4052-56' 3916-22' Operations Planned: SWAB TEST 4010-14' 3884-90' 3748-56' Time From To DAILY OPERATIONS 11/16/99 POOH W/TBG. LD 60 JTS RU ATLAS WIRELINE RIH FL @ 700' PERFORATE 1948-60' 5 JSPF 4 1/2" ALPHA JET CASING GUN NO APPARENT FLUID OR GAS ENTRY RD ATLAS WIRELINE PU BAKER MODEL G RBP AND TIH. SET RBP AT 2019' POOH W/TBG. PU BAKER FULLBORE TENSION PACKER AND TIH. SET PACKER AT 1904' W/40,000# TENSION SWIFN COSTS PREVIOUS DAILY CUMULATIVE Rig $54,675 $4,250 $58,925 S u pervision $10,500 $750 $11,250 Rentals $6,200 $600' $6,800 Roustabouts $1,200 $0 $1,200 Transportation $9,584 $0 $9,584 Cement, Acid, Frac. $5,940 $0 $5,940 Perforating, Logging $8,143 $2,834 $10,977 Subsurface Pumps $0 Rods, Scrapers $500 $0 $500 Tubing, Subs, SN $0 TAC, Packer, Repair $7,375 $4,480 $11,855 Others $0 Location $750 $0 $750 Misc. $0 Electrical $0 Water $4,100 $520 $4,620 Contingency $10,897 $1,343 $12,240 TOTAL $119,864 $14,777 $134,641 OCEAN E N E RGY . sou.c s. ,.c. PIONEER UNIT #1702-15DD Location: SEC 15 T17N R2W Date: 11/18/99 11/17/99 BREAKDOWN PERFS 1948-60' Work Done on: Present Operation: Peris: TD/PBTD: KB/GL Others: Peris: DALLY RIG REPORT N/A 4120' 264'/253' PKR ~ 3722' 4052-56' 3916-22' Operations Planned: SWAB TEST 4010-14' 3884-90' 3748-56' Time From To DAILY OPERATIONS il 1/17~99 SITP 0 PSI NO FLAMMABLE GAS TO SURFACE RU TO SWAB IFL 700'. SWAB TO XN NIPPLE @ 1904' IN 2 RUNS RECOVERED 7 BBL FLUID MADE 1 RUN/2 HRS FOR 6 HRS W/NO RECOVERY SWlFN 7 BBL TOTAL FLUID RECOVERED COSTS PREVIOUS DAILY CUMULATIVE Rig $58,925 $2,686 $61,611 Supervision $11,250 $750 $12,000 Rentals $6,800 $600 $7,400 Roustabouts $1,200 $0 $1,200 Transportation $9,584 $0 $9,584 Cement, Acid, Frac. $5,940 $0 $5,940 Perforating, Logging $10,977 $0: $10,977 Subsurface Pumps $0 Rods, Scrapers $500 $0 $500 Tubing, Subs, SN $0 TAC, Packer, Repair $11,855 $0 $11,855 Others $0 Location $750 $0 $750 Misc. $0 !Electrical $0 Water $4,620 $520 $5,140 Conti n g e n c¥ $12,240 $456 $12,696 TOTAL $134,641 $5,012 $139,653 OCEAN ENERGY . sou.o s, iNC. PIONEER UNIT #1702-15DD Location: SEC 15 T17N R2W Date: 11/19/99 Work Done on: 11/18/99 Present Operation: SWAB TEST PERFS 1948-60' Perfs: TD/PBTD: KB/GL Others: Perfs: DALLY RIG REPORT N/A 4120' 264'/253' PKR ~ 3722' 4052-56' 3916-22' Operations Planned: SI FOR HOLIDAYS 4010-14' 3884-90' 3748-56' Time From To DAILY OPERATIONS 11/18/99 SITP 0 PSI NO FLAMMABLE GAS TO SURFACE RU TO SWAB IFL 1100'. SWAB TO XN NIPPLE @ 1904' IN 2 RUNS RECOVERED 4 BBL FLUID RU BJ SERVICES TO BREAKDOWN PERFS 1948-60' BD W/50 BBL 2% KCL WATER + 1% EDTA + .5% NONIONIC SURFACTANT W/75 1.3 SP. GR. BALL SEALERS AS FOLLOWS: FILL TBG AND ESTABLISH INJECTION AT 1620 PSI ~ 1/4 BPM BROKEDOWN TO 1525 AT 1/4 BPM INCREASE RATE TO 1 BPM (~ 1680 PSI INCREASE RATE TO 2 BPM (~ 1770 PSI INCREASE RATE TO 3 BPM (~ 1880 PSI INCREASE RATE TP 4 BPM ~ 1970 PSI INCREASE RATE TO 6 BPM @ 2030 PSI PRESSURE INCREASED W/BALLS ON PERFS TO 5.7 BPM 2090 PSI ISIP 1505 PSI 5MINSI 1304PSl 10MINSl 1263PSl 15MINSI 1230PSI RD BJ SERVICES RU TO FLOW BACK FLOWED TO TANK FOR 30 MINUTES RECOVERED 6 BBL FLUID RU TO SWAB SWAB TO XN NIPPLE IN 5 RUNS ~RECOVERED 18 BBL FLUID WAIT 1 HR AND MADE 1 ADDITIONAL RUN FL @ 1100'. RECOVERED 5 BBL ADDITIONAL FLUID. SWIFN 190 BBL TOTAL LOAD 29 BBL TOTAL LOAD RECOVERED. COSTS PREVIOUS DAILY CUMULATIVE Rig $61,611 $3,750 $65,361 Supervision $12,000 $750 $12,750 Rentals $7,400. $600 $8,000 Roustabouts $1,200 $0 $1,200 Transportation $9,584 $0 $9,584 Cement, Acid, Frac. $5,940 $3,349 $9,289 Perforating, Logging $10,977 $0 $10,977 Subsurface Pumps $0 Rods, Scrapers $500 $0 $500 Tubing, Subs, SN $0 TAC, Packer, Repair $11,855 $0 $11,855 Others $0 Location $750 $0 $750 Misc. $0 Electrical $0. Water $5,140 $520 $5,660 Contingency $12,696 $897 $13,593 TOTAL $139,653 $9,866 $149,519 OCEAN ENERGY RESOURCES, INC. DAILY RI ~"~~RT Well: Location: Date: Work Done on: Present Operation: PIONEER UNIT #1702-15DD SEC 15 T17N R2W 11/20/99 11/19/99 SI FOR HOLIDAYS Perfs: TD/PBTD: KB/GL Others: Perfs: N/A 4120' 264'/253' PKR (~ 3722' 4052-56' 3916-22' Operations Planned: 4010-14' 3884-90' 3748-56' Time From To DAILY OPERATIONS 11/19/99 SITP 2O0 PSI FLAMMABLE GAS TO SURFACE. FLARE OFF IN 30 SECONDS RU TO SWAB IFL 200'. SWAB TO XN NIPPLE (~ 1904' IN 3 RUNS RECOVERED 9.4 BBL FLUID MADE 1 RUN/HR FOR 8 HRS RECOVERED 16 BBL ADDITIONAL FLUID FFL 1450' FINAL RATE 2 BPH SLIGHTLY GAS CUT FLUID SWIFN 25.4 BBL RECOVERED FOR DAY 90 BBL TOTAL LOAD 54.4 BBL TOTAL LOAD RECOVERED SI UNTIL 11/30/99 DRYWATCH PERSONNEL ON LOCATION 24 HRS COSTS PREVIOUS DALLY CUMULATIVE Rig $65,361 $3,750 $69,111 S u pe rvisio n $12,750 $750 $13,500 Rentals $8,000 $600 $8,600 Rou sta bo uts $1,200 $0 $1,200 Transportation $9,584 $0 $9,584 Cement, Acid, Frac. $9,289 $0 $9,289 Perforating, Logging $10,977 $0 $10,977 Subsurface Pumps $0 Rods, Scrapers $500 $0 $500 Tubing, Subs, SN $0 TAC, Packer, Repair $11,855 $0 $11,855 Others $0 Location $750 $0 $750 Misc. $0 Electrical $0 Water $5,660 $774 $6,434 . Contingency $13,593 $587 $14,180 TOTAL $149,519 $6,461 $155,980 OCEAN ENERGY DAILY RIG REPORT Location: Date: 12/2/99 Work Done on: 12/1/99 Present Operation: PIONEER UNIT #1702-15DD Perfs: N/A SEC 15 T17N R2W TD/PBTD: 4120' KB/GL 264'/253' Others: RETRIEVE RBP Perfs: 4052-56' 3916-22' Operations Planned: PERFORATE 1420-28' 4010-14' 3884-90' 1948-60' 3748-56' Time From To DAILY OPERATIONS 11/20 - 11/29 SI FOR HOLIDAY 24 HOUR DRY WATCH ON LOCATION 11/30/99 .. :RIG TRANSMISSION PROBLEMS SD FOR REPAIRS 12/1/99 REPAIR RIG TRANSMISSION SlTP 20 PSI RU TO SWAB FL (~ SURFACE MADE 1 SWAB RUN AND RECOVERED FLUID SAMPLE FOR ANALYSIS RELEASED PACKER AND POOH W/TBG. SWIFN COSTS PREVIOUS DAILY CUMULATIVE Rig $69,111 $9,770 $78,881 S u pervisio n $13,500 $1,500 $15,000 Rentals $8,600 $600 $9,200 Roustabouts $1,200 $0 $1,200 Transportation $9,584 $0 $9,584 Cement, Acid, Frac. $9,289 $0 $9,289 Perforating, Logging $10,977 $0 $10,977 Subsurface Pumps $0 Rods, Scrapers $500 $0 $500 Tubing, Subs, SN $0 TAC, Packer, Repair $11,855 $0 $11,855 Others $0 Location $750 $0 $750 Misc. $0 Electrical $0 Water $6,434 $0 $6,434 Contingency $14,180 $1,187 $15,367 TOTAL $155,980 $13,057 $169,037 OCEAN ENERGY RESOURCES, INC. Well: PIONEER UNIT #1702-15DD Location: SEC 15 T17N R2W Date: 12/3/99 Work Done on: 12/2/99 Present Operation: SWAB TEST ZONE 1420-28' Peris: TD/PBTD: KB/GL Others: Peris: DALLY RIG REPORT N/A 4120' 264'/253' PKR @ 1368' 4052-56' 3916-22' Operations Planned: 1420-28' 4010-14' 3884-90' 1948-60' 3748-56' Time From To DAILY OPERATIONS 12/2/99 SlCP 0 PSI PU RETRIEVINGHEAD AND RIH W/TBG. RELEASE MODEL G RBP AT 2020'. POOH W/TBG AND RBP. RU BAKER ATLAS WIRELINE PERFORATE 1420-28' 5 JSPF 4 1/2" ALPHA JET CASING GUN SET BAKER WIRELINE SET TUBING RETRIEVABLE BP AT 1475' RDMO BAKER ATLAS PU RETRIEVING HEAD AND BAKER FULLBORE TENSION PACKER. TIH W/44 JTS TBG. SET PACKER AT 1368' W/30,000# TENSION. SWIFN COSTS PREVIOUS DAILY CUMULATIVE .Rig $78,881 $3,750 $82,631 Supervision $15,000 $750 $15,750 Rentals $9,200 $600 $9,800 Roustabouts $1,200 $0 $1,200 Tra n s portation $9,584 $0 $9,584 Cement, Acid, Frac. $9,289 $0 $9,289 Perforating, Logging $10,977 $4,650 $15,627 Subsurface Pumps $0 Rods, Scrapers $500 $0 $500 _Tubing, Subs, SN $0 TAC, Packer, Repair $11,855 $3,475 $15,330 Others $0 Location $750 $0 $750 Misc. $0 Electrical $0 Water $6,434 $520 $6,954 Contingency $15,367 $1,375 $16,742 L TOTAL $169,037 $15,1201 $184,157 OCEAN ENERGY PIONEER UNIT #1702-15DD Location: SEC 15 T17N R2W Date: 12/4/99 Work Done on: 12/3/99 Present Operation' SWAB TEST ZONE 1420-28' Perfs: TD/PBTD: KB/GL Others: Perfs: DALLY RIG REPORT N/A 4120' 264'/253' PKR (~ 1368' 4052-56' 3916-22' Operations Planned: BREAKDOWN PERFS 1420-28' 4010-14' 3884-90' 1948-60' 3748-56' Time From To DAILY OPERATIONS 12/3/99 SlTP 0 PSI RU TO SWAB IFL 350' SWAB TO XN NIPPLE AT 1378' IN 2 RUNS ,.. RU BJ SERVICES TO BREAKDOWN PERFS 1420-28' FILL TUBING AND ESTABLISH RATE W/80 BBL 2% KCL WATER +.5% NONIONIC SURFACTANT AND 1% EDTA. ESTABLISHED PUMPIN AT 1/4 BPM 960 PSI INCREASE RATE TO 1 BPM 1160 PSI INCREASE RATE TO 3 BPM 1390 PSI INCREASE RATE TO 5 BPM 1630 PSI FINAL PUMPIN 1830 PSI 6 BPM. ISlP 830 PSI 15 MINUTE SI 720 PSI RDMO BJ SERVICES BLED TBG TO TANK IN 2 MINUTES RU TO SWAB SWAB TO XN NIPPLE (~ 1378' IN 5 RUNS MADE 3 ADDITIONAL RUNS RECOVERED 16 BBL TOTAL FLUID 54 BBL LOAD REMAINING SWlFN .. ,. COSTS PREVIOUS DAILY CUMULATIVE Rig $82,631 $3,750 $86,381 ..Supervision $15,750 $750 $16,500 Rentals $9,800 $600 $10,400 Roustabouts $1,200 $0 $1,200 Tra n spo rtation $9,584 $0 $9,584 Cement, Acid, Frac. $9,289 $3,341 $12,630 Perforating, Logging $15,627, $0 $15,627 Subsurface Pumps $0 Rods, Scrapers $500 $0 $500 Tubing, Subs, SN $0 TAC, Packer, Repair $15,330 $0 $15,330 Others $0 Location $750 $0 $750 Misc. $0 iElectrical $0i Water $6,954 $850 $7,804 ! Conti ngenc¥ $16,742 $929 $17,671 TOTAL $184,157 $10,220 $194,377 OCEAN ENERGY Well: PIONEER UNIT #1702-15DD Location: SEC 15 T17N R2W Date: 12~5~99 Work Done on: 12/4/99 Present Operation: SWAB TEST ZONE 1420-28' Perfs: TD/PBTD: KB/GL Others: Perfs: DAILY RIG REPORT N/A 4120' 264'/253' PKR ~ 1378' 4052-56' 3916-22' Operations Planned: BREAKDOWN PERFS 1420-28' 4010-14' 3884-90' 1948-60' 3748-56' Time From To DAILY OPERATIONS 12/4/99 SITP 180 PSI BLED TO 0 IN 30 SEC. NO GAS TO SURFACE TRU TO SWAB IFL @ SURFACE SWAB TO XN NIPPLE AT 1378' IN 2 RUNS MADE 1 RUN/HR FOR 7 HRS FINAL FL 1250' FINAL RATE 1/4 BPH 10 BBL TOTAL FLUID RECOVERED FOR DAY 26 BBL OF 80 BBL LOAD RECOVERED SWIFN COSTS PREVIOUS DAILY CUMULATIVE Rig $86,381 $3,750 $90,131 Supervision $16,500 $750 $17,250 Rentals $10,400 $600 $11,000 Roustabouts $1,200 $0 $1,200 Transportation $9,584 $0 $9,584 Cement, Acid, Frac. $9,289 $0 $9,289 Perforating, Logging $15,627' $0 $15,627 Subsurface Pumps $0 Rods, Scrapers $500 $0 $500 Tubing, Subs, SN $0 TAC, Packer, Repair $15,330 $0 $15,330 Others $0 Location $750 $0 $750 Misc. $0 Electrical $0 Water $7,804 $0 $7,804 Contingency $17,337 $510 $17,847 TOTAL $190,702 $5,610 $196,312 OCEAN ENERGY . sou.c s, iNC. Well: PIONEER UNIT #1702-15DD Location: SEC 15 T17N R2W Date: 12/6/99 12/5/99 PERFORATE 938-48' Work Done on: Present Operation' Perfs: TD/PBTD: KB/GL Others: Perfs: DALLY RIG REPORT N/A 4120' 264'/253' PKR ~ 1378' 4052-56' 3916-22' Operations Planned' SWAB TEST 1420-28' 4010-14' 3884-90' 1948-60' 3748-56' Time From To DAILY OPERATIONS 12/5/99 SITP 0 PSI NO GAS TO SURFACE RU TO SWAB IFL (~ 850' 400'FLUID ENTRY OVERNIGHT SWAB TO XN NIPPLE AT 1378' IN 2 RUNS MADE I RUN/HR FOR 3 HRS FINAL FL 1250' FINAL RATE 1/4 BPH 3 BBL TOTAL FLUID RECOVERED FOR DAY ;29 BBL OF 80 BBL LOAD RECOVERED ~RELEASE PACKER PU 4 JTS TBG RETRIEVE RBP POOH W/TBG. SWIFN COSTS PREVIOUS DAILY CUMULATIVE Rig $90,131 $3,750 $93,881 S u pe rvisio n $17,250 $750 $18,000 Rentals $11,000 $600 $11,600 Roustabouts $1,200 $0 $1,200 Transportation $9,584 $0 $9,584 Cement, Acid, Frac. $9,289 $0 $9,289 Perforating, Logging $15,627 $0 $15,627 Subsurface Pumps $0 Rods, Scrapers $500 $0 $500 Tubing, Subs, SN $0 TAC, Packer, Repair $15,330 $0 $15,330 Others $0 Location $750 $0 $750 Misc. $0 Electrical $0 Water $7,804 $0 $7,804: Contingency $17,847 $510 $18,357 ~ TOTAL $196,312 $5,610 $201,922! OCEAN E N E RGY sou c s. ,.c. PIONEER UNIT #1702-15DD Location: SEC 15 T17N R2W Date: 12/7/99 12/6/99 SWAB TEST 938-48' Work Done on: Present Operation: Perfs: TD/PBTD: KB/GL Others: Perfs: DALLY RIG REPORT N/A 4120' 264'/253' PKR @ 906' 4052-56' 3916-22' Operations Planned: BD PERFS 1420-28' 4010-14' 3884-90' 938-48' 1948-60' 3748-56' Time From To DAILY OPERATIONS 12/6/99 SITP 0 PSI NO GAS TO SURFACE RU BAKER ATLAS WIRELINE EQUIPMENT FL (~ 650' PERFORATE 938'-48' 5 JSPF 4 1/2" ALPHA JET CASING GUNS WIRELINE SET BAKER TUBING RETRIEVABLE BRIDGE PLUG (~ 1000' RIH W/BAKER FULLBORE TENSION PACKER AND RETRIEVING HEAD SET PACKER W/29 JTS TBG IN HOLE AT 906' RU TO SWAB IFL 650' SWAB TO XN NIPPLE AT 899' RECOVERED 2 BBL FLUID MADE 1 RUN/HR FOR 3 HRS W/NO FLUID RECOVERY SWIFN COSTS PREVIOUS DAILY CUMULATIVE Rig $93,881 $3,750 $97,631 Supervision $18,000i $750 $18,750 Rentals $11,600~ $600 $12,200 Roustabouts $1,2001 $0 $1,200 Transportation $9,584; $0 $9,584 Cement, Acid, Frac. $9,289; $0 $9,289 Perforating, Logging $15,627, $4,384 $20,011 Subsurface Pumps $0 Rods, Scrapers $500 $0 $500 Tubing, Subs, SN $0 TAC, Packer, Repair $15,330 $3,540 $18,870 Others $0 Location $750 $0 $750 Misc. $0 Electrical $0 Water $7,804 $520 $8,324 Contingency $18,357 $1,354 $19,711 TOTAL $201,922 $14,898 $216,820 OCEAN ENERGY Well: PIONEER UNIT #1702-15DD Perfs: Location: SEC 15 T17N R2W TD/PBTD: Date: 12/8/99 KB/GL Work Done on: 12/7/99 Others: Present Operation: SWAB TEST 938-48' Perfs: DALLY RIG REPORT N/A 4120' 264'/253' PKR (~ 906' 4052-56' 3916-22' Operations Planned' ACIDIZE PERFS 938-48' 1420-28' 4010-14' 3884-90' 938-48' 1948-60' 3748-56' Time From To DAILY OPERATIONS 12/7/99 SlTP 0 PSI NO GAS TO SURFACE RU TO SWAB NO FLUID RECOVERY RU BJ SERVICES TO BD PERFS 93-48'. BD FLUID 50 BBL 2% KCL WATER +.5% NONIONIC SURFACTANT + 1% EDTA FILL TBG AND ESTABLISH INJECTION AT 1/4 BPM 565 PSI INCREASE RATE TO 1 BPM 670 PSI INCREASE RATE TO 2 BPM 790 PSI INCREASE RATE TO 4 BPM 870 PSI NO APPARENT BD WHILE INJECTING INCREASE RATE TO 5 BPM 980 PSI DISPLACE W 25 BBL 2% KCL WATER FINAL PI 5 BPM 1050 PSI ISIP563PSI 15MINSI 513PSI RDMO BJ SERVICES BLED TBG TO TANK IMMEDIATE BLEEDOFF RU TO SWAB SWAB TO XN NIPPLE AT 899' IN 1 RUN MADE 1 RUN/HR FOR 4 HRS 9 BBL TOTAL FLUID RECOVERED OF 65 BBL LOAD FFL 800' FINAL RATE 1/2 BPH. SWIFN I COSTS PREVIOUS DAILY CUMUL~,TIVE Rig $97,631 $3,750 $1~1,381 Supervision $18,750 $750 $19,500 Rentals $12,200 $600 $12,800 Roustabouts $1,200 $0 $1,200 Tra nspo rtation $9,584 $0 $9,584 Cement, Acid, Frac. $9,2891 $3,275 $12,564 Perforating, Loggin~l $20,011 $0 $20,011 Subsurface Pumps $0 Rods, Scrapers $500! $0 $500 Tubing, Subs, SN $0 TAC, Packer, Repair $18,870 $0 $18,870 Others $0 Location $750 $0 $750 Misc. $0 Electrical $0 Water $8,324 $790 $9,114 Contingency $19,711 $917 $20,627 TOTAL $216,820 $10,082 $226,901 OCEAN ENERGY RESOURCES, INC. DALLY RIG REPORT Well: Location: Date: Work Done on: Present Operation: PIONEER UNIT #1702-15DD SEC 15 T17N R2W 4120' 12/9/99 264'/253' 12/8/99 Perfs: N/A TD/PBTD: KB/GL Others: PKR (~ 906' SWAB TEST 938-48' Perfs: 4052-56' 3916-22' 1420-28' 4010-14' 3884-90' Operations Planned: 938-48' 1948-60' ' }-56' Time From To DAILY OPERATIONS 12/8/99 SITP 0 PSI NO GAS TO SURFACE Aias~ RU TO SWAB FL (~ 600'. 300' FLUID ENTRY OVERNIGHT RU BJ SERVICES TO BD PERFS 93-48' W/ACID. BD FLUID 500 GAL 7 1/2% HCL ACID +.2% INIHIB +,5% NONIONIC SURFACTANT + 1% EDTA FILL TBG AND ESTABLISH INJECTION AT 1/4 BPM 565 PSI INCREASE RATE TO 3 BPM 810 PSI FLUSH W/18 BBL 2% KCL WATER FINAL PI ~ 3 BPM 790 PSI ISIP 563 PSI 15 MIN SI 503 PSI SWAB TO XN NIPPLE IN 2 RUNS MADE 1 RUN/HR FOR 4 HRS 7 BBL TOTAL FLUID RECOVERED OF 30 BBL LOAD SWIFN COSTS PREVIOUS DAILY CUMULATIVE Rig $101,381 $3,750 $105,131 S u pe rvi'~o n $19,500 $750 $20,250 Rentals $12,800 $600 $13,400 Roustabouts $1,200 $0 $1,200 Transportation $9,584 $0 $9,584 Cement, Acid, Frac. $12,564 $3,865 $16,429! Perforating, Logging $20,011 $0 $20,011 Subsurface Pumps $0 Rods, Scrapers $500 $0 $500 Tubing, Subs, SN $0 TAC, Packer, Repair $18,870 $0 $18,870 Others $0 Location $750 $0 $750 Misc. $0 Electrical $0 Water $9,114 $790 $9,904 Contingency $20,627 $976 $21,603 TOTAL $226,901 $10,731 $237,632 OCEAN ENERGY . sou.cES.,NO. PIONEER UNIT #1702-15DD Location: SEC 15 T17N R2W Date: 12/10/99 Work Done on: 12/9/99 Present Operation: SWAB TEST 938-48' Perfs: TD/PBTD: KB/GL Others: Perfs: DALLY RIG REPORT N/A 4120' 264'/253' PKR (~ 906' 4052-56' 3916-22' Operations Planned: RETRIEVE PACKER AND RBP 1420-28' 4010-14' 3884-90' 938-48' 1948-60' 3748-56' Time From To DAILY OPERATIONS 12/9/99 SlTP 0 PSI NO GAS TO SURFACE RU TO SWAB FL (~ 500'. 400' FLUID ENTRY OVERNIGHT SWAB TO XN NIPPLE IN 2 RUNS MADE 1 RUN/HR FOR 7 HRS 6 BBL TOTAL FLUID RECOVERED FOR THE DAYOF 30 BBL LOAD FINAL FL 825' FINAL SWAB RATE 1/4 BPH 13 OF 30 BBL LOAD RECOVERED SWIFN COSTS PREVIOUS DAILY CUMULATIVE Rig $105,131 $3,750 $108,881 :Supervision $20,250 $750 $21,000 Rentals $13,400 $600 $14,000 Roustabouts $1,2001 $0 $1,200 Transportation $9,584 $0 $9,584 Cement, Acid, Frac. $16,429 $0 $16,429 Perforating, Logging $20,011 $0 $20,011 Subsurface Pumps $0 Rods, Scrapers $500 $0 $500 Tubing, Subs, SN $0 TAC, Packer, Repair $18,870 $0 $18,870 Others $0 Location $750 $0 $750 Misc. $0 Electrical $0 Water $9,904 $520 $10,424 Contingency $21,603 $562 $22,165 TOTAL $237,632 $6,182 $243,814 OCEAN ENERGY PIONEER UNIT #1702-15DD Location: SEC 15 T17N R2W Date: 12/11/99 Work Done on: 12/10/99 Present Operation: SWAB TEST ALL ZONES Perfs: TD/PBTD: KB/GL Others: Perfs: DALLY RIG REPORT N/A 4120' 264'/253' PKR ~ 906' 4052-56' 3916-22' Operations Planned: 1420-28' 4010-14' 3884-90' 938-48' 1948-60' 3748-56' Time From To DAILY OPERATIONS 12/10/99 SlTP 0 PSI NO GAS TO SURFACE RU TO SWAB FL (~ 500'. 400' FLUID ENTRY OVERNIGHT SWAB TO XN NIPPLE IN 2 RUNS RECOVERED 2 BBL FLUID 15 OF 30 BBL TOTAL LOAD RECOVERED RD SWAB EQUIPMENT RELEASE PACKER PU 3 JTS TBG. RETRIEVE RBP AT 1000' POOH W/TBG. LD PACKER AND RBP. RIH 2.205" ID XN NIPPLE AND 70 JTS 2 7/8" J-55 EUE TUBING. LAND TUBING AT 2176.35' ND BOPE. NU WELLHEAD. SWIFN. COSTS PREVIOUS DALLY CUMULATIVE Rig $108,881 $3,750 $112,631 Supervision $21,000 $750 $21,750 Rentals $14,000 $600 $14,600 Roustabouts $1,200 $0 $1,200 Transportation $9,584 $0 $9,584 Cement, Acid, Frac. $16,429 $0 $16,429 Perforating, Logging $20,011 $0 $20,011 Subsurface Pumps $0 Rods, Scrapers $500 $0 $500 Tubing, Subs, SN $0 TAC, Packer, Repair $18,870 $0 $18,870 Others $0 Location $750~ $0 $750 Misc. $0 Electrical $0 Water $10,424 $520 $10,944 Contingency $22,165 $562 $22,727 TOTAL $243,814 $6,182 $249,996 OCEAN ENERGY RESOURCES, INC. DALLY RIG REPORT Well: PIONEER UNIT #1702-15DD Perfs: Location: SEC 15 T17N R2W TD/PBTD: Date: 12/12/99 KB/G L Work Done on: 12/11/99 Others: Present Operation: SWAB TEST ALL ZONES Perfs: N/A 4120' 264'/253' TBG SET @ 2176' 4052-56' 3916-22' Operations Planned: RDMO SERVICE UNIT 1420-28' 4010-14' 3884-90' 938-48' 1948-60' 3748-56' Time From To DAILY OPERATIONS 12/11/99 SITP 0 PSI NO GAS TO SURFACE RU TO SWAB FL (~ 400' SWAB ALL ZONES COLLECTIVELY. APR 26 ~/lnn SWAB TO XN NIPPLE @ 2176' IN 4 HRS RECOVERED 48 BBL FLUID ,-wv MADE 1 RUN/HR FOR 4 HRS RECOVERED 8 BBL ADDITIONAL FLUID ¢~tllt~0~d~/'~ ~,.,,,,...... FFL 1800' FINAL RATE 2 BPH. ~tn.,,.h~m'"''''''"~ SWIFN. ,. .. .. COSTS PREVIOUS DALLY CUMULATIVE .Rig $112,631 $3,750 $116,381 Supervision $21,750 $750 $22,500 Rentals $14,600 $600 $15,200 Roustabouts $1,200 $0 $1,200 .Transportation $9,584 $0 $9,584 cement, Acid, Frac. $16,429 $0 $16,429 Perforating, Logging $20,011 $0 $20,011 Subsurface Pumps $0 Rods, Scrapers $500 $0 $500 Tubing, Subs, SN $0 TAC, Packer, Repair $18,870 $0 $18,870 Others $0 Location $750 $0 $750 Misc. $0 Electrical $0 Water $10,944 $520 $11,464 (3ontingenc¥ $22,727 $562 $23,289 TOTAL $249,996 $6,182 $256,178 OCEAN ENERGY . sou.c s, iNC. Well: PIONEER UNIT #1702-15DD Location: SEC 15 T17N R2W Date: 12/13/99 Work Done on: 12/12/99 Present Operation: SI Perfs: TD/PBTD: KB/GL Others: Perfs: DALLY RIG REPORT N/A 4120' 264'/253' TBG SET (~ 2176' 4052-56' 3916-22' Operations Planned: 1420-28' 4010-14' 3884-90' 938-48' 1948-60' 3748-56' Time From To DAILY OPERATIONS 11/12/99 SITP/CP 0/0 PSI NO GAS TO SURFACE ON TBG OR ANNULUS RU TO SWAB IFL (~ 1600' SWAB ALL ZONES COLLECTIVELY. SWAB TO XN NIPPLE (~ 2176' IN 2 RUNS RECOVERED 4 BBL FLUID MADE I RUN/HR FOR 4 HRS RECOVERED 8 BBL ADDITIONAL FLUID FFL 1800' FINAL RATE 2 BPH. RDMO SERVICE UNIT. COSTS PREVIOUS DAILY CUMULATIVE Rig $116,381 $3,750 $120,131 Supervision $22,500 $750 $23,250 Rentals $15,200 $600 $15,800 Roustabouts $1,200 $0 $1,200 Transportation $9,584 $4,600 $14,184 Cement, Acid, Frac. $16,429 $0 $16,429 Perforating, Logging $20,011 $0 $20,011 Subsurface Pumps $0 Rods, Scrapers $500 $0 $500 Tubing, Subs, SN $0 TAC, Packer, Repair $18,870 $0 $18,870 Others $0 Location $750 $0 $750 Misc. $0 Electrical $0 Water $11,464 $520 $11,984 Contingency $23,289 $1,022 $24,311 TOTAL $256,178 $11,242 $267,420 BJ Services Company REMIT TO: P,O. BOX 843710 DALLAS, TX 75284-3710 §16721 11E~81D026 CUSTOMER NO. COST CENTER YOUR ORI]ER NO 20030017 ! 385 Ooean Energy, Inc. 410-17th St. Denver Ccdo~do 80202 SE]~/IC~.5 FROM OUR STATION AT Ninth Slope Cementing FOR SERVICE t/il'ELL NAME ! 702-15-DD PRODUCT CODE 100021 100112 100295 121106 121116 J396 M100 A694 F003 JO50 .~391 J401 DESCRIPTION Class G Cement Calcium Cldm~le Cello Flake Cemenl Plug. Rubber. Boltom 9-518 in Ceme~l Plug. Rut]be[, Top 9-5/8 in Remote Locatie~ Crow Expense/Man Equiprnerd operator surlace chan:je Misceli~teous Service Charges Bulk Materials Service Charge Testing BOP, O- 5000 psi Testing BOP, atte[ 2 hfs Cemenl Pump Casir~j. 501 - 1013~) fl Fas. Lek Cement Head Dala Aqmsibon. Cement. Standard Mileage. Auto. Rck-Up o[ Treatin§ Van I~ulk Ue~efy, Dry Pmdu~s 1~.. : ..... ..i,. ,~ ........... i',i ,'1-... -. ' ' ...'~..~..,~--i ........ ;'.:[ 0~'~I~TOT~ UIIIT OF MEASURE · ea clay 2hfs hrs 6hfs iob · .miles PHONE: (713)462-.4239 TERMS: NET 30 DAYS QUANTII'V 400 752 150 ! 1 69' 20 40O I I I I 44O 4136 ILl RERV1CE$ SUPF_RV1SOR SIC. d~_O FOR YOU BY F~yd Poage J; Dennis Ackerman COUI'f~/~ARiSH STATE Ke~ai A~aska LJsT PRICE UNIT 15.400 0.750 2.300 341.000 183.000' 135.0O0 52.500 52.500 1.600 855.t300 185.000 1,420.000 260.000 670 I]0(J 2 150 1·200 GROSS PERCENT NET AIm3UNI' DISC. AIIIOUNT 564.00 75% 423.00: 345.00 25% , Z58.75i 341.00: 7.5% 255.751 183.00 25% 137.25; 135.00 2:5% 101 3,622.50 25% 2,716.&8i 1,0.50.00 25% 787.50: 640.001 25% ' 480.0oi 8~s.oo! 25%~ 92.$.00i 25%i 693.75! 1,42000: 25% i 260.00' 25%~ 195.00! 670.00. 25% 502_50: 946.00. 25% 709.50 i 4,963.20 25% 3,722.40 i 23,079.70~ 11,3419.78! RECEIVED Ai Oil & Gas Cons. mie n 17.30978 i -FIELD RE. CF_tPT NO. 1166100:;lG BJ S=rvic~.s Comp&ny · II 11 · -- II hi ;.; II III 2CX3~011 - OOIS~Z2 CITY Oerr.'~ ..................... i He,,a Well JOB DEPTH (fi) ...... 681 Gain .................................................... lB UI~LL [I~PTH(II) gAS USED ON JO8: 061 flo ........ ....... ~u~~ ~T~ ~ 1 Y~ C~E: STATE CeK~r~da ZIP CODE Ut~ ~ ME ASLI~ il°b QUANTITY FRIll_ UNIT ............ ¥ .......... ~o oX) 1 67u.17,X) INVOICE NUISIBUi .... AMOUMT 641.25 ................ . .............................. GRO~ ' PERCENT AMC)LWT DISC. 1,420.(]0'. . . ~_~ .... ARRIVE ~o.! OAY jYEAJI; IlM! LOCAT$ON' O~ I I :a'I '*999 ! .............................. SEE LAST PAGE FOR GENE~L TERMS AND CONDITIONS 4,~01 25% 17,300.7e SERVICE ORDER; I AqTHORIZE WORK TO BEOIM PER SERVICE 5E, nq~CE I~E,,C,~PT: I CkHI'II~t' THAT Tiff./~IA'ITr'Jql/U.,~ &NO 5 ER'VI,CF,.$ LISTED V',/~fl-~, - x .......... ~ ////~._,_ ~. ! ~~,;-,~ ..... ......................... 1 .... ~->"'-'~i~iii~AbT-"O~Z~OA~'"T .... .... i..":. , - ........... I X _-'~~'_, ,, ........ _.. '-, i Pa.qe 2 ':"': FIELD RECEIPT NO. 116810025 i~' - ' ~ f~2_~ · [LRI E V~:3RK MO. DAY COMPLETED Q;) 17 '-EU SERI/ICE$ DLe~IRICI' )Cella1, AK ,_ WELL ~ ~ NUMBER WELL t.OCA'i'lO,~l · aTREEI' ~ 10X NUMBER 410.-17~1 ~. Suffe · 1Sr:~J FI~I Po~e Jr WELL 1YPE: .Ne Well LEGAL DESI:RIPIIO~ Eq'~IprneM O~rator . _, Mac Cme..~ Pumpl~Q, 3C~$- 4000 J22S ! O~ Acc~slllon, Cement, JOB DEP1.H (fl) ; WEU. CLASS: ........ [ JOB ~E CO~: .l~ l[~ .Pump- I~ T~I .... . : ~~..* ...... , . ~.. · '.,~:. 6 1 UdLq~l ~""E RUMBER · i'AMOq, jMT." 'ARRIVE faO. ii)AY 'VK&J't TIME ISERVICI:ORDER:IAUTHORIZEWORKTOBEGINISERSiERI,/ICE 1'SERIa~-I~¢EiPT:ICEH11FY11~l:/H~'M~TEk-I~K~SNIDI~CESL~T~WEK ..........LOCATION': ....... Og J 17 1~ ItO'3)~INgTRU~TfONSINACCORDANCEW1THTHEIT:RMSANDCONOIIIQMSIRLr~ANOALLsERVICEnI~w'"°RMLtDmAw°R~Mn~NIR -- - 'PRINTEDON TI'IF. LAST PAGE OF 1115 FORM AND REPRESENT TI'ULTI ~- .................................... '--SE--'E-~:.~i~-PAO~ FOR GENERAL ' · FIELD RECEIPT NO, BJ $~rvicss ! I -i" i Comp;ny CU$,~OMER {CO),IPANY NAMEI : ~DIT ~~ ~n ~,~, Inc. ;REQ ......... I~O~E 10- 4t~t ~ St. Sull~ 1~ ..................... DATE ~K MO. DAY Y~ W~LL ~PE: C~IRETED ~ i 17 ..... . ~ SE~*~ES OlSTmGT ~B ~(fl) ~C~SS: ........... Kend. AK ~i Da6 ~L ~ME ~O NUMBER 10 W~L D~TH(I) - - G~ USED ~ ~8 ~'-- - -. ~AT~M' ....... W~llla ....... ~J ........... ~r~ ......... ~u.~ce C~ OEl~lON M~B~ ~ PRICE UNff "' '~-~- '~.. oc~ .................... ......... ~ .... i __ SUB-TOTAL FOR Pr~ M~ ................................. . . ~' - , ~ipmeM o~ ~ cha~e .................. .~ .... :~[~~;~~=~ -- ;. ...... ~? .... - ~ ~ ......... -~'~ I CUSTQMER IlILlUlER _1~77- _oo~222 __ STATE ~ CODE Colorado 1:IO2OZ ..................... GROa$ (~.I(~C).C)~ ~-~ar.~-~ ..... .Er,. msc, -I :.-AMOUNT il . .... ~ii,' ~5~6 II)! 25% 2.716.88 BJ Services Company 4!l)-l;'th st. Sui~ 1400 Demur Colorado j I00112 1OO12O 10O275 100316 ; 398211 · MIO0 · I PHOIIE: (]'13)4624239 hrs cuff 6bm h~ PRICE UNIT --" 15.,~1~ 0.7f~ 0.2.2~ 5~1 1.854] 431~ 0.26(] 1~ 116 ~.~{ 78181 14~ 1.2~ RECEIVED 11,242.0~ 142.78 1,019.35 1,1311.1~] 6 1,911.60 1,249.60 2,565.0O .670.00 17,50~.60 IPEm3~ NEt 25~ 25~ 25% 25% 25% 25% 25% 25% 2514, 25% 25~ 25~ 25% 25~ 25~ 25% 57.38 IDT.09 764.51 854.10 4,72~75 1,433.70 937.20 1,923.75 I I ~. BJ Services Company Ocean Energy, Inc. 410-t711'1 SL Suite 1400 Denver Colorado 80202 ' ~oDUCT GOOF. A136 J99~.5 J9985 J9965 Fl05 J225 PHONE: (3'13) 462.4239 REIBT TO: P.O. BOX 043710 DALLAS, 'TX 75184-3710 SUB TOTAL RECEIVED Naska 0il & Gas Cons, Comm~o Aq~ora~ 819560 11871D047 1O/CI6/I ~ CU~TOII~ NO. :COST ~R' 201330017 ~ 1385 I · SER'4~ FROM (RJR STATION AT !North SI~ Cen~r~ FOR SERVICE WELL NAME 1702-15DD Robert Moore . Cooper · "coLwrYm.~u~ i sr, iE :Anchorage iAtaska MEASURE QUANTITY lea !4h~ NET 30 DAYS 24i ,52.54X)~ 33.000: 16.O00i 1; 2,2.00.0001 670.000:" GR(~'- ,PERCI~rr AMOUNT i DISC, 1,260.00 25% 184.50 16.00 O% 2,20~.00 25% 670.00 25%, ; 4,963.50 ; · .. NET AMOUNT 945.00 184.50 16.00 50Z.50 I 3,331.00~ fiELD I~CEFT NO. I. BJ Services Company I I I I __--- - Y ' - __ i ii i iml iii i i _i ii · · I Jl · · iii _ ~i _ I__ ,?. 1,_,,0 .... RECEIVED com~'~ .~i~lI c"~-~' I,,.~a.,~,,~ . · ~~: ~~s,n~ ~ . ~ _ ,. ~~.. ~..~:..,~;.....:,-a:.-.,.; .~ s:'.~.:s:6:;~.::C.' ?`:.~(~:~a.~:~.;;~:.~`.;~b:~...y.~s;..~i;.~.:;..~.::::~?;~s..~:~;..::.:~`.s~.~ .::...:,:.~.-~:-.~:-~...-..:.,:, k:~:":-)~.:)~.~:~i:.:.~.?~.~' ..... ~--.: :.,. ?.~...-..- ...... . .... . ....... .:~..,~.:- :~?~.~:~ ~'' ~ ....... ~ ..... ~ ~ ~ ~ ............. " ' ~ I' ' ,. - ...... ._~ ..... . ....... ~ ........ a~m~~~~ .. ,. '." ~.= .... ~ .~ ~:, ..... ,: .. ......... , .... , ,.. .... ; , , ,, ,, .. I ................... t ...... [ ....... ~~-~,--t~~~~~--~~t~ - ~ i //~ _ ~~te~For~~ -~~~~~/ ~ ~. .. . .. ~~- ~ ~ RECBPT NO. ~IBIIM~I ...... II~ i Il I , I I l__ ,, ..... I Illl__ III · II II I I I III I I I_ I__! II I -- BJ FIELD RECEIPT NO. 118710047 ( BJ Services Company ) .__=_ ........ £-::;~--_ '". _-'-_-,~.._~.~[,7____~-~-- ...... I COMPLETEO I~J ~RVICES OISlRICT Ocman MAIL SI'IM~T C:~ lOX NUMIEX I(enaL AK WELL NAME ANO NUMBER 17Q2-15OD WELL Lg~CATION: AKa6 ~ !Equtpmenl Operal~ ~jat~ lcar~~ _ DaM AcRuis, l:i~, CemeM, S~'x~i~d !-,~ oEPm ~ J22f.~ CITY lN~Wea RE~~D JTD WELL DEPTH(A) 4JmO SUB-TO TAt Fo-R'.~t~oe CtI~Ts FIELO ~.S_ TIMAI'£t "-.::: -..-~.o~-~~;':::: :- : ..-1 --f ......... i- ...... -~ - t -~-- ..... ................ ~~ ............ ........ : ~. .... I_. -~-~P~D~THE~STPAGE~ SEE ~ST PAGE FOR GENE~L ~ ....... ~~~ ......... I _ ~,~~~ ' ~'~ 10021 )0112 )0120 )0275 :)0316 )8211 2252.8 ~1013 136 It00 010 038 050 225 391 ,' 401 PFK:)NE: (7t3) Pi~._.£ER UNIT FLUID SAMPLE ANALYSIS 11/2/99 COMPONENT UNIT BASE #1 #2 #3 v~4 #5 CHLORIDE mg/I 9920, 8690 5960 78501 4990 SULFATE mg/I 25i 37.21 27.8 26.31 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 HARDNESSasCaCO3 !mg/I 192 1580 1710 22 324 !Sp. Gr. !SpG@25c 1.018 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 ZONES 3748-56' 3884-90' 3916-22' DARK RED WATER 2% BS #3 10/13/99 10/18/99 11102/99 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 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Robert Christenson~V DATE: Chairman THRU: Blair Wondzeli, ~ FILE NO: P. I. Supervisor ~)/'~-(93 FROM: John H Spauidin~//~o4~t SUBJECT: Petroleum Inspec[or September 18, 1999 CH&P rig 23.doc BOPE Test CH&P rig 23 Ocean Energy Pioneer Unit well 15-DD PTD 99-66 September 18, 1999: i traveled to Ocean Energy's well 15-DD located near Big Lake, AK to witness the BOPE test on CH&P rig 23. The AOGCC BOPE Test Report is attached for reference. As noted on the test report 2 failures were observed, the kill line manual valve leaked and was greased and returned to service testing ok, the floor safety valve failed and a replacement was being sent out from Anchorage. The rig appeared to be in good condition, with good access on all sides. SUMMARY: I witnessed the BOPE Test on; CH&P rig 23, 2 failures, 6 hour test time Attachment: CH&P 23.xls STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Ddg: Ddg Contractor: Operator: Well Name: Casing Size: Test: Initial X Workover: DATE: 9/18/99 CH & P Rig No. 23 PTD # 99-66 Rig Ph.# 373-1037 Ocean Ener~Ty Rep.: Dennis Ackerrnan 15-DD Rig Rep.: Brian Busby Set @ Location: Sec. 14 T. 17N R. 2W Meridian Seward Weekly Other MISC. INSPECTIONS: Location Gen.: ok Housekeeping: ok (Gen) PTD On Location ok Standing Order Posted ok Well Sign ok Drl. Rig ok Hazard Sec. ok FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure P/F I 250/2, 500 P I 250/2, 500 P I 250/2, 500 F I 250/2, 500 P BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press P/F 250/2, 500 P 250/2,500 P 250/2, 500 CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure P/F 5 25072, 500 P 13 250/2, 500 P 2 P Functioned Functioned P 250/2, 500 P I 250/2,50O P I 250/2,500 F* ACCUMULATOR SYSTEM: I 250/2,500 P System Pressure 1,100 J P Pressure After Closure 1,000 J P MUD SYSTEM: V"~sual Alarm 200 psi Attained After Closure minutes 40 sec. Tdp Tank ok ok System Pressure Attained I minutes 34 sec. Pit Level Indicators ok ok Blind Switch Covers: Master: X Remote: Flow Indicator ok ok Nitgn. Btl's: 3 ~2300 AVG. Meth Gas Detector ok ok Psig. H2S Gas Detector ok ok Number of Failures: 2 ,Test Time: 6.0 Hours. Number of valves tested 12 Repair or Replacement of Failed Equipment will be made within 1 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 ]:nspector North Slope Pager No. 659-3607 or 3687 If your call is not retumed by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Distribution: odg-Well File c - Oper./Rig c- Database c - Tdp Rpt File c- Inspector STATE W~q'NESS REQUIRED? YES X NO 24 HOUR NOT~CE G~EN YES X NO Waived By: VV'Cmessed By: John H. Spauiding F1-021L (Rev. 12/94) CH & Pdg 23 9: 27AM OCEAN ENERGY RESOURCES ~ .NO. 686 P. 4/5 ~ J- ,STATE OF ALASKA '~ ALASKA O-~,...AND GAS CONSERVATION ~.-~MMISSION APPLICATION FOR SUNDRY APPROVALS 1. Ty!~e of Request: Abandon: Suspend: Opemti'~n shutdown: Re-shier suspended well: Alter casing: Rel3alr Well', P!ugglng: Time ex[enslon'. Stlmul~;te: Change approved program: Pull tubing: Variance: XX Perforate: Othe~ 2. Name ef Operator .... 5. Type of well; ~. Datum elevation (DF or KB) O~n Energy, Inc. Developm~nt: X KB: 284' feet 3, Addr~s Ex~loratow; 7, Unit or Pra~ name $tmtigr~hlc', 1670 Broadway, Su~ 2800, Denver, CO. 602024826 So.ice: Pioneer Unit 1702 4. Location of well a[ surface 8, Well number 793' FEL &171' FSL See, ~8-T17N-R2W 15DD At ~o~ of ~rodu~Ne inte~al g. Permit number 9~ At e~dNe dep~ 793' FEL &171' FSL Se~ 15-Tt7N-R2W 10. APl number 50- 00g-2~017 At total depth 793' FEL &171' FSL Sec, 15-T17N-R2W 11. Ffeld/Pool Pioneer Unlt~enek ..... 1~. Present well ~ndEi~ summaw Total depth: measured fee~ Plugs (measured) tree ve~l f~t Effete depth: measured feet JuPk (measure) trna ve~l Casing Length Size Cemented Mea~red depth Tree ve~ical depth Structural Co~u~tor Su~ace lnte~ediate Produ~lon Tubing (s~e, gra~e, and measured depth) ,{',"iS.<a 0ii & Oas Cons. Commission Palm and $SSV (~pe and measured deplh) 13. AEachamen~s Des~pt~n summa~ of proposal: X ~talled operations p~: ..... 14. Est[ma~ed date for ~mmenclng operation 15. Stat~ of ~11 classification spudded 8/28/g9 at ~:~AM. 16, If proposal wel~ve~l~ ~p~'wd= ................... Oil: Gas: X Suspended: Name of a~mver Blair ~sdz~[l__ ?2~/9~___Dm~.app~?~d._ 17, I he~y ce~ that ~e foregoing Is true and co~e~ [o the be~ of my kn0~edge, 8~ned: ~~ C~ T~e:' R.ula~ Co~lnator Da.'. 8/30~9 FOR COMMISSION USE ONLY PI~ int~ ~OP Test Lo~tien clearance . . Me~anl~l Imegrie Test ' ~;~sequent fo~ r~ui~ 10- ~O~ ORIGINAL SIGNED BY Approved by o~er of th. Commissioner Robe~ N. Christenson com?s,ioner Form 10-403 Rev 06/'15/88 SUBMIT IN TRIPLICATE .~9 9: 27AM OCEAN ENERGY RESOURCES M0.686 P.5/5 August30,1999 Pioneer Unit 1702 #15DD Section 15-T17N-R2W Matanuska-Susitna Borough Diverter Vadance Request At this time OEi is requesting a va~nce on the stipulation that a 13 $-/8" diver[er be used on the #15DD well while the well is spudded and the conductor pipe is set. Set the surface conductor to 35' and then use the normal set-up for the remainder of the well, with out a diverter on the stack. When OEI was drilling the Pioneer Unit 1702 #15DA WIW, 'located (+-) 1183 feet to the north of the #15DD location, no shallow gas zones were present in the upper zones where the conductor pipe was set. Re: Pioneer Unit 1702 # 14cc well, ...7N-R2W, M_~atanuska-Susitna Borough .... , Subject: Date: From: Organization: To: CC: Re: Pioneer Unit 1702 #14CC well, 500' FWL & 820' FSL Sec 14-T17N-R2W, Matanuska-Susitna Borough. Thu, 26 Aug 1999 15:40:11 -0800 Blair Wondzell <blair_wondzell~admin.state.ak.us> i~merr, a~. State of Alaska, Dept of Admin, Oil & Gas "Webb, S. (Scott)" <Scott. Webb~OceanEnergy.com>, Camille Oechsli <cammy_oechsli@admin.state.ak.us> "Wilson, Chuck" <Chuck. Wilson@OceanEnergy.com>, Robert Crandall <bob_crandall~admin.state.ak.us>, Robert Christenson <robert_christenson~admin.state.ak.us> Scott, Bob Crandall and I evaluated this request and discussed it with commissioners Christenson and Oechsli. We have determined that we can give verbal approval to the waiver of the diverter on Pioneer Unit well 1702-14CC pending formal approval via a 10-403. At your earliest convience, please prepare and submitt a 10-403 for formal approval. Blair Wondzell 8/26/99 "Webb, S. (Scott)" wrote: Mr. Wondzell, Ocean Energy, Inc. (OEI) is planning on spudding the subject well on either Friday the 27th of August or Saturday the 28th of August. At this time OEI is requesting a variance on the stipulation that a 13 3-/8" diverter be used on the #14CC well while the well is spudded and the conductor pipe is set. Instead, we would just set the surface conductor to 35' and then use the normal set-up for the remainder of the well, with out a diverter on the stack. When OEI was drilling the Pioneer Unit 1702 #15DA WIW, located (+-) 1300 feet to the west of the #14CC location, no shallow gas zones were present in the upper zones where the conductor pipe was set. I can be reached at the above listed E-mail address or by my direct telephone line at (303) 308-8863. Thank you for your time and help in this matter. Scott Webb 1 of 1 8/30/99 4:13 PM STATE OF ALASKA .LASKA OIL AND GAS CONSERVATION COMMIS DESIGNATION OF OPERATOR 20 AAC 25.020 Name and Address of Owner: Union Oil Company of California PO Box 196247 (909 W. 9th Avenue) Anchorage, AK 99519-6247 p¥ Notice is ereby given of a designation of operatorship for the oil and gas property described below: Legal description of property: See attached Exhibit - L~%f.,. o..~.~... ~ Property Plat Attached Name and Address of Designated Operator: Ocean Energy Resources, Inc. 1001 Fannin, Suite 1600 Houston, Texas 77002 4. Effective date designation: July 1, 1999 Acceptance of operator~}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 torney- i n-Fact The owner here~/certifies that the foregoing is true and correct. Name (printed) Kevin A. Tablet Date ~ (,~ Title (printed) Attorney-in-Fact Date Approve ~ Approved ~_ ~ _~'~_,' '~ (Requires two signatures)'~~ND GAS C~ATION Form 10-411, Rev. 01-08-92 COMMISSION Date Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage Alaska 99501-3192 Re~ THE APPLICATION OF Union Oil Company ) Company of California for an order granting ) an exception to the spacing requirements of ) 20 AAC 25.055(a)(2) to provide for the drilling ) of the Pioneer Unit 1702-15DD and 1702-14CC ) exploratory gas wells to an unde£med gas pool in ) the Matanuska Valley in Southcentral Alaska ) Conservation Order No. 447 Well 1702-15DD Well 1702-14CC Pioneer Unit July 13. 1999 IT APPEARING THAT: , Umon Oil Company of California ("Unocal") by letter dated June 3.1999, requested an exception to the well spacing provisions of 20 AAC 25.055(a)(2). The exception would allow drilling the Pioneer Unit 1702-15DD and 1702-14CC exploratoo' gas wells to bottomhole locations closer than 1500 feet to a section line. The Commission published notice of opportunity for public heanng in the Anchorage Daily News on June 9. 1999, pursuant to 20 AAC 25.540. 3. The Commission did not receive any protests to the application. FINDINGS: The Pioneer Unit 1702-15DD well will be drilled as a vertical hole from a surface location 150' from the south line (FSL), 440' from the east line, Section 15. T17N, R2W, Seward Meridian (SM). The Pioneer Unit 1702-14CC well will be drilled as a vertical hole from a surface location 720' FSL, 660' from the west line, Section 14, T17N, R2W, Seward Meridian (SM). 3. The Pioneer Unit 1702-15DD and 1702-14CC wells are within 3.000 feet of each other. . Offset OX~T~ers Cook Inlet Region, Inc.: Universits.; of Alaska: and Alaska Mental Health Trust have been duly notified. 5. An exception to the well spacing provisions of 20 AAC 25.055(a)(2) is necessary to allow the drilling of these wells. Conservation Order No.-,.,7 Julv 13. 1999 Page 2 CONCLUSION: 1. Granting a spacing exception to allow drilling of the Pioneer Unit 1702-15DD and 1702-14CC wells will not result in waste. . Since the wells are within 3000 feet of each other, if both wells are determined to be capable of producing from the same pool, the Commission must establish drilling units or prescribe a spacing pattern for the pool, prior to any production from either well. NOW, THEREFORE, IT IS ORDERED: Unocal's application for exception to the well spacing provisions of 20 AAC 25.055(a)(2) for the purpose of drilling the Pioneer Unit 1702-15DD and 1702-14CC wells is approved. DONE at Anchorage, Alaska and dated July 13. 1999. Alaska Oil and Gas Conservation Commission Camill60echsli, Commissioner Alaska Oil and Gas David W. J~ Alaska Oil Commission AS 31.05.080 provides that within 20 days after receipt of xwitten notice of the entry of an order, a person affected by it may file with the Commission an application for rehearing. A request for reheating must be received by 4:30 PM on the 23ra day following the date of the order, or next working day ifa holiday or weekenck 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 bv not acting on it within the 10-day period. An affected person has 30 days from the date the Cmnmission refuses the application or mails (or otherwise distributes) an order upon rehearing, both being the final order of the Conunission. to appeal the decision to Superior Court. Where a request for rehearing is denied by nonaction of the Commission. the 30-day period fbr appeal to Superior Court rum from the date on which the request is deemed den/ed (i.e.. 10~ day after the application ~br rehearin~ was filed). Initial Pioneer Unit Drilling Programs; Ocean F~ergy Subject: Initial Pioneer Unit Drilling Programs; Ocean Energy Date: Tue, 06 Jul 1999 15:42:43 -0800 From: Robert Crandall <Bob_Crandall~admin.state.ak.us> Organization: DOA-AOGCC To: "Wondzell, Blair" <blair_wondzell~admin.state.ak.us> CC: "Christenson, Robert" <robert_chfistenson@admin.state.ak.us> Blair: The subject wells are located 5 to 6 miles from the Arco BLT #1 well. Ocean has asked to drill the first 700 feet of these wells without a diverter. Using the BLT #1 as control, we can expect glacial deposits to about 550' below ground level. These are predominately gravels with volumetrically minor and not very continuous shales. The lack of a good seal in this portion of the section makes the potential for a gas show here very low. The 150-200' of Tyonek has some potential for shallow gas both in conventional reservoirs and in coal seams. Controlled drilling and tripping procedures should be used here particularly if the diverter waiver is granted. Let me know if I can be of some further help Bob Crandall 1 of 1 7/12/99 9:29 AM TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 August 4. 1999 Scott Webb RegulatoD' Coordinator Ocean Energy Resources. Inc. 1670 Broadway, Suite 2800 Denver, CO 80202-4826 Re: Pioneer Unit 1702 15DD Ocean Energy Resources. Inc. Permit No: 99-66 SurLoc: 171'FSL. 793'FEL. Sec. 15, T17N. R2W. SM Btmhole Loc. 171'FSL. 793'FEL. Sec. 15. T17N. R2W. SM Dear Mr. Webb: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill 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. Your request for diverter waiver is approved. 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 thc Commission to witness a test of BOPE installed prior to drilling new hole. Notice may bc given by contacting the Commission at 279-1433. Robert N. Christenson. 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 ..... AND GAS CONSERVATION CO;--~;,/IISSION PERMIT TO DRILL 1 a. Type of work Drill: X Redrill: I I b. Type of well Re-Entry: Deepen:I Service: 2. Name of Operator Ocean Energy, Resources, Inc. 3. Address 1670 Broadway, Suite 2800, Denver, CO 80202-4826 4. Location of well at surface 171' FSL & 793' FEL At top of productive interval 171' FSL & 793' FEL At total depth 171' FSL & 793' FEL Sec 15-T17N-R2W 12. Distance to nearest property line 171' feet 13. Distance to nearest well NA feet Exploratory: X Stratigraphic Test: Development Oil: Deve!opement Gas: X Single Zone: Multiple Zone: 5. Datum Elevation (DF or KB) GL: 253' KB: 264' feet 6. Property Designation ADL-374117 7. Unit or property Name Pioneer Unit j ~(~)~ 8. Well number -.l-T-e~15 DD 9: Approximate spud date Upon Approval 14. Number of acres in property 16. To be completed for deviated wells Kickoff depth: feet Maximum hole angle: 18' Casing pr°gram ! I Settini Depth size Specifications Top Hole I Casing Weight I Grade I Couplingl Length MD I ~V~ UD 10. Field and Pool Tyonek 11. Type Bond (see 20 AAC 25.025) Number JZ-8072 Amount $200,000.00 15. Proposed depth (MD and TVD) 2721.06 4,100' feet 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Maxirnum surface 1410 psig At total depth (TVD) 1500 psig Bottom I TVD Quantity of cement (include stage data) 17-1/2" 13-3/8" 68~ J-55 ST&C 35' Surf. Surf. 35' 35' 35 sx 12-1/4" 9-5/8" 36# J-55 ST&C 700' Surf. Surf. 700' 700' I 400 sx 8-3/4" 7" 23~ WC-50 ST&C 4100' Surf. Surf. 4100' 4100' 1st 221 sx 2nd 121 sx 3rd 113sx I I 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet true vertical feet Effective depth: measured feet true vertical feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured Length Size true vertical Plugs (measured) Junk (measured) Cemented Measured depth True vertical depth 20. Attachments: Filing fee: XX Property Plat: XX BOP Sketch: XX Diverter Sketch: NA Drilling fluid program: XX Time vs. depth plot: Refraction analysis: Seabed report: Drilling program: 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: 6/28/99 Permit Number ISee cover letter for other requirements Mud log required: [ ]Yes J~ No ~ No Commission Use Only J APl number J Appro~ date Conditions of approval Samples required: [ ] Yes ~ No Hydrogen sulfide measures [ ] Yes I~ No Directional survey required [ ] Yes Required working pressure forBOPE L~2M; [ ]3M; [ ]5M; [ ]10M; [ ]15M Other: ORIGINAL SIGNED BY Approved by F{ob~rl; N. Chdstenson Commissioner Form 10-401 Rev. 12-1-85 20 AAC 25.005 by order of the Commission Submit in triplicate June 28, 1999 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: Pioneer Unit #1702-15DA Section 15-T17N-R2W Matanuska-Susima Borough Pioneer Unit # 1702-15DD Section 15-T17N-R2W Mamnuska-Susima Borough Pioneer Unit # 1702-14CC Section 14-T17N-R2W Mamnuska-Susitna Borough Dear Madam or Sir; Enclosed are the originals and two copies of the application to drill and the required attachments for the subject wells. 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 Ocean Energy Resources, Inc. Amoco Building 1670 Broadway, Suite 2800 Denver, Colorado 80202 (303) 308-8500 Fax: (303) 308-8510 Pioneer Unit #~ ~2-15DD Proposed Completion SE SE Section 15-T17N-R2W Matanuska-Susitna Borough, AK GL: 253' 2 Well Detail/Casing Detail 1) Conductor: 13-3/8"/68# / K-55 / Welded @ 35'/17-1/2" hole. Cemented with 35 sx 2) Surface: 9-5~8" / 36~ / J-55 / STC @ 700' / 12-1/4" hole. Cemented with 400 sx "G". 3) Production: 7" / 23# / WC-50 / LTC @ 4,100' / 8-3~4" hole. Cemented to surface with 455 sx "G". 4) Tubing:2-7/8"/6.5# / J-55 / EUE 8rd @ 50' above top perfs. 5) Packer @ 50' above top perfs. 6) Perforations Between 1,500' and 4,000' (estimated) 7) TD: 4,100' 6 7 3 DRILLING PROGNOSIS PIONEER UNIT "TIGHT HOLE" WELL: #1702-15DD FIELD: Pioneer Unit DIRECTIONS to LOCATION: From Anchorage, AK: SURFACE LOCATION: SE SE Section 15, T17N, R2W, Matanuska-Susima Borough, Alaska ELEVATIONS: GL: 253' & KB: 264' ESTIMATED TD: 4,100'MD PRIMARY OBJECTIVE: Tyonek Formation DRILLING CONTRACTOR: CH&P Drilling Company ON-SITE CONSULTANT: Dennis Ackerman ON-SITE GEOLOGIST: Noel Waechter 1999 PIONEER UNIT DRILLING PIONEER PROSPECT Itl 702-15DD Section 15, T17N-R2W Matanuska-Susitna Borough, Alaska GENERAL 1.) Ocean Energy, Inc has approved drilling and completion of a test of the Tyonek formation in the Pioneer Prospect of Alaska. The well name, AFE number and AFE cost are listed below. Well Name AFE # # 1702-15DD DND972 AFE'd Costs Dryhole Costs: Completion Costs: Total D&C Costs: $354,325. $418,785. $773,110. 2.) The #1702-15DD well is on fee land, and we currently have drilling permits issued from the State of Alaska. All applicable State & BLM guidelines shall be adhered to during this project. As a minimum, they should be notified of the following events. a.) 24 Hrs. before spudding. b.) 24 Hrs. before NU BOPE. c.) 24 Hrs. before running all casing strings. 3.) Morning reports shall be faxed to both the Denver and Gillette offices by 7:00 am Rocky Mountain Time every morning. See phone list for fax numbers. Daily report will include: Depth (TVD & MD); Operations; Formation; Bit No. (size, type, and grade when pulled); Weight on Bit; Rotary Table RPM; Pump Pressure; Annular Velocities around DP & DC's; HHP at bit; Each DC ID & OD; BHA with Lengths and ID's & OD's; Surveys (azimuth, bearing X-Y coordinates, total displacement); Mud Properties (weight, viscosity, water loss, filter cake, % solids, % LCM, pH, chlorides, gel strengths, PV, YP, Ca, materials used, daily and total mud costs) 4.) All costs are to be carded on the daily drilling report. A 10% contingency shall be added to all items except for footage, daywork and casing costs to cover taxes and any missed costs. 5.) We will be drilling on fee land. OEI currently has a good working relationship with the surface owner, therefore, every effort to keep trash cleaned up, traffic and road damage to a minimum and mn a "clean" operation should be made during drilling and completion of this well. PIONEER #1702-15DD MATANUSKA-SUSITNA BOROUGH, AK DRILLING PROGRAM L O CA TION: There are no planned mud pits. All drilling fluids will be handled through a closed loop mud system. Have water tested for potential problems by both the mud engineer and BJ Services engineer prior to spudding. Locate an emergency response trailer in an accessible area on the drilling location upwind from the wellhead. Install H2S monitors at the bell nipple, cellar, shaker, and rig floor. Set and cement conductor (minimum of 12-3/4" drift ID) to +/-35 feet. NU diverter and lines onto the conductor. SURFACE HOLE: Surface to 700' A 12-1/4" surface hole will be drilled to a minimum depth of 700' using 4-1/2" DP as supplied by the drilling contractor. Surveys should be taken every 300'. Maximum deviation is to be 3 degrees, maximum dogleg severity is to be 1 degree/100 Ft. The mud system will consist of fresh water with prehydrated bentonite. Utilize all solids control equipment. Pump sweeps if required. Save and condition mud for use in 8-3/4" hole. SURFACE HOLE MUD PROGRAM: MI (MI Gel, MI Bar, Soda Ash, Caustic Soda, Gelex) Depth: 0' to 700' Spud with fresh water. Allow viscosity to increase and if necessary, treat any fluid loss with Polypac prior to running casing. Weight (ppg) 8.6 to 9.0 Viscosity (sec) 28 to 40 Filtrate (mi) No Control pH No Control PV (cp) 15 to 20 YP (lbs/100 fta) 15 to 25 Undissolved Solids (%) 0 to 5 SURFA CE CASING: The surface casing will be 9-5/8", 36 #/Ft J-55 ST&C top to bottom. The float equipment will be a 9-5/8" guide shoe, an insert float (auto-fill), nine (9) centralizers and one stop ting. Place centralizers on the middle of the first joint with a stop ring, first four collars, and every other collar for eight collars thereafter. Thread lock guide shoe, shoe joint and float collar. Depth Interval Casing Burst/SF Collapse/SF 0'- 700' 9-5/8" 36#/ftJ-55 STC 3,520psi/8.80 2,020psi/6.313 TensionfSF 394 Mlbs/15.63 (J) PIONEER #1702-15DD MATANUSKA-SUSITNA BOROUGH, AK SURFACE HOLE: Surface to700' (continued) SURFA CE CASING CEMENT PROGRAM: BJ Services out of Kenai, AK will be pumping the cement, the proposed cementing program is listed below based on 100% excess. Minimum WOC time per the Drilling Contract is 8.0 Hrs. - 10 Bbls. of fresh water spacer with 2 galfobl SAPP -400 sxs "G" cmt + 2.0 % CaC12 and 1 gal/100 sx FP-6L -Displace with fresh water. Cement Properties "G' Slurry Weight (g/Gal) Slurry Yield (Cubic-Ft/Sx) Mix Water Required (gal/sx) Estimated Pump Time (HH:MM) 15.80 1.16 5.00 2:30 Compressive Strength: 24.0 Hr. ~ 100 Deg. F (psi) 4,000 NOTE: Surface casing must be cemented to surface. If necessary, 1" to surface with Class "G" + 2% CaCI2 after approval of the AOGCC and OEI's Denver office. WELLHEAD and BLOWOUT PREVENTION: Cut off9-5/8" casing and weld on an 11" 3M x 9-5/8" SOW casinghead. Nipple up BOP equipment and test with third party tester. Record BOPE tests on charts to provide to the AOGCC. Notify the AOGCC 24 hours prior to testing of BOPE to allow them to witness the test. BOP equipment will consist of a 3000 psi, double ram preventor with pipe and blind rams, as well as an annular preventor. After installation of BOP's, perform an accumulator test. Close the Blind Rams, pressure test BOP & Manifold to 2500 psi.for 30 mins. After testing of the Blind Rams & Manifold, pressure test the Pipe Rams to 2500 psi for 30 mins with a joint of drill pipe. Release the Pipe Rams after testing, and close the Annular Preventor for a test to 2000 psi for 30 mins. Record all test results on chart and report on daily drilling report. PIONEER #1702-15DD MATANUSKA-SUSITNA BOROUGH, AK PRODUCTIONHOLE: 700' TO 4,100' Aiier successful testing of BOP equipment to 2500 psi, test the surface casing shoe to 2500 psi then drill out of the 9-5/8" surface casing with an 8-3/4" bit using surface hole mud. Important Notes during Drilling of Production Hole: 1. Always establish circulation at the surface casing shoe while tripping back in the hole. e Always wash and ream the last two (2) joints of drill pipe to bottom while tripping back to bottom e Always slow trip speed down to no more than 60 seconds per stand below 2500 ii to prevent formation breakdown from hole surging. 4. If possible, Always wash and ream the last 60' of hole drilled before making a connection. 5. Keep hole full at all times! 6. Absolutely, No Smoking, Alcohol or Firearms on Location. PR OD UCTION HOLE MUD PROGRAM: MI (MI Bar, Soda Ash, Polypac, Soltex, Desco CF, Bicarb, Caustic Soda, PolyPlus RD, and Tannathin) The production hole will be drilled with as few chemical additions as possible. Well conditions will dictate fluid decisions. Preparations and materials will be available to weight up, viscosify, or disperse this system as hole conditions warrant. Use surface mud to drill 9-5/8" float collar, cement and shoe, then treat the fluid for cement contamination. Continue drilling ahead and allow weight to increase from drill solids to 9.5 ppg. Use dispersants as necessary to keep viscosity under 75 sec/qt. Weight up system if necessary to control pressurized inflow. Use centrifuge only as necessary to control viscosity and yield point. Lower fluid loss with Polypac only if directed by the OER! representative on location. Be prepared for potential gas kicks or water flows when drilling below 1,800'. Depth: 700' to TD Weight (ppg) Viscosity (sec) AP1 Filtrate (mi) HTHP (cc) PV (cp) YP (lbs/100 ft2) Solids (lgs) Build production hole mud from surface hole mud 10.0 to 11.5 75 or less 10 or less N/C 30to 35 20 to 25 13 to 24% PIONEER #1702-15DD MATANUSKA-SUSITNA BOROUGH, AK PROD UCTION HOLE: 700' TO 4,100' (Continued) Logging Program: The following log program will be ran as a minimum. DIL/SF.L-SP-GR-CAL and Sonic: Run from TD to base of surface casing with GR to surface. CNL/FDC-GR: Run from TD to base of surface casing Note: - Tool insurance should not be taken. -A 3-1/2" disk of each log in LAS format should be sent to the Denver office. - Logs should befaxed to the Denver office as soon as thefieldprints are available. Coring: Cores may be cut through the Tyonek formation on the second or third well across the Tyonek P Coal or the Tyonek BLT Coal to allow determination of reservoir properties. Geology: Formation #1702-15DD GL = 253' KB = 264' Glacial Gravel Tyonek Tyonek B Coal Tyonek B Sand Tyonek C Sand Tyonek C Coal Tyonek P Coal Tyonek BLT Sand Tyonek BLT Coal Estimated TD Depth / SS Datum Surface/(264') 510'/(-246') 1,030'/(-766') 1,300'/(-1,036') 1,765'/(-1,501') 2,250'/(-1,986') 3,175'/(-2,911') 3,420'/(-3,156') 3,600'/(-3,336') 4,100'/(-3,836') Geologist/Mudlogger ~Samples: There will be a 'formal' mudlogger and trailer on this well from 1,750' to TD. Sample intervals to be determined by wellsite geologist. PR OD UCTION CASING & CEMENTING 7" casing will be nm to TD, and we are planning on cementing this string with a three stage cement design. Stage tools will be nm in the 7" casing at +/-2,700' and +/-1,400'. BJ Services out of Kenai, AK will be pumping the cement job. Depth Interval Casing Burst/SF Collapse/SF 0' - 4,100' 7" 23#/ft WC-50 LTC 4,000 psi/1.75 3,110 psi/1.36 Tension/SF 287 Mlbs/3.75(J) PIONEER #1702-15DD MATANUSKA-SUSITNA BOROUGH, AK PROD UCTION HOLE: 700' ro 4, l oo' (Continued) PR OD UCTION CASING & CEMENTING (continued): The float equipment will be a 7" guide shoe, differential fill float collar, thirty (30) centralizers and one stop ring. Place centralizers in the middle of first joint with a stop ring, on the first four collars, and on every other collar for the next 50 joints. Thread lock the guide shoe onto the bottom joint. Stage Collars will be nm at 2,700' and 1,400' to allow pumping of first stage of cement across Pay Sections, then a second stage and third stage of filler cement to a planned TOC at surface. Thread lock the stage collars onto the next joint of casing above. Cement Program -20 bbls Mud Clean II -lst Stage: 221 sxs "G" Cmt + 0.3% CD32, 0.4% FL33, 1 gal/100 sxs FP6L, & 0.3% SMS -Drop plug, displace with fresh water and bump plug to 1,000 psi -Drop ball to open stage tool located at 2,700' and circulate bottoms up with fresh water -Allow a total of 4hrs WOC after 1 ~ stage before pumping 2na stage -10 bbls Mud Clean II -2nd Stage: 121 sxs "G" Cmt + 0.75% CaC12, 0.4% CD32, 1 gal/100 sxs FP6L, & 2.0% SMS -Drop plug, displace with fresh water, bump plug and close stage tool at 2,700' -Drop ball to open stage tool located at 1,400' and circulate bottoms up with fresh water -Allow a total of4hrs WOC after 2nd stage before pumping 3rd stage -10 bbls Mud Clean II -3rd Stage: 113 sxs "G" Cmt + 1.00% CaC12, 0.4% CD32, 1 gal/100 sxs FP6L, 2.0% SMS -Drop plug, displace with fresh water, bump plug and close stage tool at 1,400' -Bleed pressure off well and wait on cement Cement Properties Slurry Weight (g/Gall) Slurry Yield (Cubic-Ft/Sx) Mix Water Required (gal/sx) Estimated Pump Time (HH:MM) 1st Stage 2nd Stage 3rd Stage 15.80 12.50 11.50 1.15 2.10 2.11 4.95 11.96 11.98 4:00 4:00 4:00 Compressive Strength: 24.0 Hr. ~ 200 Deg. F (psi) 24.0 Hr. ~ 165 Deg. F (psi) 24.0 Hr. ~ 210 Deg. F (psi) 4,000 575 575 Note: Cement volumes are based on 30% excess. When caliper log is obtained, 1 st Stage is to cover from TD to 2,700'. 2nd Stage Lead slurry is to cover from 2,700' to 1,400'. 3rd Stage slurry is to cover from 1,400' to surface. Verify volumes with Denver office & BJ prior to pumping. Wellhead: Land casing in full tension & set slips. ND BOPE & Make cut on 7" casing. Nipple up tubing head. PIONEER #1702-15DD MATANUSKA-SUSITNA BOROUGH, AK VENDORS & PRICING Dirt Contractor: To be determined Conductor & Cellar: To be determined Water: To be determined Drilling Contractor: CH&P Drilling Company - Rig # 19 Randy Parsons - Traverse City, MI (616) 938 - 2001 Pusher: Clinton Eubanks Mobile: 0 - Herb Horn Mobile: 0 - Mob / Demob limited to $ Dayrate = S/day Casing: 700' of 9-5/8", 36#/Ft J-55 ST&C Casing, SMLS $14.50/FT, FOB Palmer, AK C&R Pipe and Steel. Inc Dennis Wilfer- Fairbanks, AK (907) 456 - 8386 4,10ff of 7", 23#/Ft WC-50 LT&C Casing $9.15/Ft, FOB Palmer, AK C&R Pipe and Steel. Inc Dennis Wilfer- Fairbanks, AK (907) 456 - 8386 Tubing: 4,000' of 2-7/8" 6.5 #/Ft L-80, EUE 8rd Tubing, ERW $3.35/Ft, Palmer, AK C&R Pipe and Steel. Inc Dennis Wilfer- Fairbanks, AK (907) 456 - 8386 Wellhead: Cameron 9-5/8" SOW x 11", 3M Casing Head = $1,480.09 11", 3M x 7-1/16", 3M x 2-7/8" Tubinghead = $10,405.83 Plus taxes and shipping Joe Brewer- Denver, CO Ken Kubiak or Pete Thoeni- Anchorage, AK (303) 861 - 1850 (907) 562- 2332 Fax: (907) 562 - 3880 Mud Company: MI Drilling Fluids John Couch- Denver, CO (303) 623 - 0911 Deen Bryan- Anchorage, AK (907) 274- 5564 PIONEER #1702-15DD MATANUSKA-SUSITNA BOROUGH, AK VENDORS & PRICING(continued) Cement Company: BJ Services Company: 9-5/8" Surface Csg- $18,768 7" Production Csg- $24,309 Dave Hencke- Denver, CO (303) 832 - 3722 J. Jay Garner- Anchorage, AK (907) 349 - 6518 On-Site Consultant: Dennis Ackerman- Anchorage, AK (907) 345 - 4712 Geologist: Noel P.. Waechter and Associates Noel Waechter-Denver, CO (303) 825- 7140 Open Hole Logging: Baker Atlas Ron Doshier- Anchorage, AK (907) 563- 3233 PIONEER #1702-15DD MATANUSKA-SUSITNA BOROUGH, AK OERI Personnel Phone List Production Manager: Douglas Walton Office: Fax #: Home: Mobile: (303) 308- 8867 (303) 308- 8697 (303) 721- 1787 (303) 898- 6920 Drilling Manager: Chuck Wilson Office: Fax #: Home: Mobile: (303) 308 - 8864 (303) 308- 8697 (720) 283- 0108 (303) 748- 3624 Engineer/Geologist: Robert Downey Office: Fax#: Home: Mobile: (303) 308- 8822 (303) 308 - 8697 (303) 850- 0284 (303) 807- 5262 Foreman: Larry Curtis Office: Fax#: Home: Mobile: (307) 746 - 4052 (307) 746- 4045 (307) 746- 2202 (307) 680- 9052 . Field Pumper: Office: Home: Mobile: _ 10 BLOWOUT PRE\ :NTER SYSTEM Pioneer Unit Ocean Energy, Inc. Fill Line Flow Line Diverter Rating' 3,000 psi Active 5,000 psi Static Annular I I I I R-Pipe Rams I I Choke Manifold Assembly for 3M WP System To Pit and/or Mud/Gas Separator Adjustible Choke Spool Kill Lines 3OOO 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 Blowout Prevention Equipment 9-5/8" BOP Equipment 1 each 9-5/8" X 3,000 psi wp single type pipe ram. 1 each 9-5/8" X 3,000 psi wp double type blind rams. 1 each 9-5/8" X 3,000 psi wp annular preventer. 1 each 9-5/8" X 3,000 psi wp drilling spool with 2 each 4" side outlets (choke and kill), HCR and manual valves 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 CH&P RIG #19 Hydraulic Oil - 100 gal. Motor Oil -200 gal. _~.. Gear Oil - 100 gal. ~ "~.,__? .... ' 4700 gal. Diesel fuel 285' bbl. Fresh Water 150 bbl. Light Plant Dog House Brine Tank Brine for Hydromatic - 220 gal. ., .,.'" Hydraulic Oil - 260 gal. i ~ Drilling Unit Mud Pump Diesel Fuel 199 gal. Rig Floor Mud Pit 300 bbl. Pipe Racks .. Cat Walk !i Reserve Pit Guylines - 60' back / 45' out from center ./lines - 60' front / 60' out from center 35 feet from center of well to reserve pit SE 1/4 SE 1/4 SECTION 15 T17N, R2W, S.M., AK PIONEER 15DD GRID N: 2761298.577-1 GRID E: 569059.97.5[ LATITUDE: 61'53'25.595'.i~ LONGITUDE: 149'56'14.775"l ~ ASP ZONE 4 NAD27 ~ ~_Proposed 171' Surface Facilities 795' AcceSS~~ South Line Section 15 Found survey monument SCALE 1"-- 200' 1) Basis of Horizontal Coordinates State of Alaska DOT&PF Georeferencing Project GPS Control Stations BigL & G40. Il OCEAN ENERGY, INC. PIONEER UNIT IH702-15DD SURFACE LOCATION 795' FEL and 171' FSL SECTION 15, T17N, R2W, S.M., AK MATANUSKA-SUSITNA BOROUGH Prepared For: Ocean Energy Inc. 1670 Broadway Suite 2800 Denver, CO 80202 Surveyed b~ 993060 Job No: ....... McLANE CONSULTING GROUP Engineers, Surveyors and Planners P,O, Box 468 Soldotna, AK 99669 99-20 June 19, 1999 Field Book No. Date: 1, 2~ ATTACHMENT #1 Oceam Energy Resources, Inc requests a waiver to not utilize a diverter during drilling of the 12-1/4" Surface Hole duc to no shallow gas down to 700' below surface. Ooean Enm~ Resoumes, Inc will perfon'a an 11,5 ppg FIT by drilling 10 feet below thc 9-5/8" Surface Casing Shoe, riga pumping to an equivalent mud weight test to 11.5 ppg at the surface casing shoe. gnchora~z Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re: Pioneer Unit Wells 1702-15DD & 1702-14CC Union Oil Company of California (Unocal) bv letter dated June 3, 1999, has requested an exception to the provisions of 20 AAC 25.055(a)(2) for the drilling of two vertical exploratoo' gas wells to an undefined gas pool in the Matanuska Valley in Southcentral Alaska. The exception would allow Unocal to drill the Pioneer Unit 1702-15DD and 1702-14CC wells to bottomhole locations closer than 1500 feet to a section line. The Pioneer Unit 1702-15DD well will be drilled as a vertical hole from a surface location 150' from the south line (FSL), 440' from the east line (FEL), Section 15, T17N, R2W, Seward Meridian (SM). The Pioneer Unit 1702-14CC well will be drilled as a vertical hole from a surface location of720'FSL, 660'FWL, Section 14, T17N, R2W, SM. A person w'ho may be harmed if the requested order is issued may file a written protest prior to 4:00 PM, June 24, 1999, with the Alaska Oil and Gas Conservation Commission, 3001 Porcupine Drive, Anchorage, Alaska 99501, and request a hearing on this matter. If the protest is timely filed and raises a substantial and material issue crucial to the to the Commission's determination, a hearing on the matter will be held at the above address at 9:00 AM on July 13, 1999, in conformance with 20 AAC 25.540. If no protest is filed, the Commission will consider the issuance of the order without a hearing. If you are a person with a disability who may need a special modification in order to comment or to attend the public hearing, please contact Diana Fleck by July 7, 1999 at 793-1221. Camm~yO hsl~' Commissioner Published June 9, 1999 ADN AO 02914031 OCEAN ENERGY RES~'--'~ICES, INC. 410-17th Street,. .e 1400 Denver, Colorado 80202 (303) 573-5100 PAY THE SUM OF One hundred and 00/100 Dollars TO THE ORDER OF NationsBank, ,. Atlanta, Dekalb County, .~eorgia 64-1276/611 No. 0500137109 DATE JUN 18,1999 AMOUNT *****$100.00 VOID AFTER 90 DAYS ALASKA OIL & GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, AK 99501 ,'0 50O ;i, =. ? i,O =i,' ' : O ;, i, l, i, ;= ? P, P, l : 3;=~I ~t=t=. ;=O=i?,' OCEAN ENERGY RESOURCES, INCA10-17th Street, Suite 1400 * Denver, Colorado 80202 * (303) 573-5100 061499C 06/14/99 342685 APD FOR PIONEER 100.00 100.00 UNIT #1702-15DD, ALASKA I WELL PERMIT CHECKLIST COMPANY~--'-'~,,"~_L~,,,? WELL NAME//-~O.2__--/',~'",/),E) PROGRAM: exp __ dev ,~ redrll __ serv __ wellbore seg ann. disposal para req __ FIEED & POOL ~"',,,/,c:~ .5'"',:::~ INIT CLASS ADMINISTRATION 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 ........... ENGINEERING APPR_ DATE 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 ..... GEOLOGY - , ANN ULAR DISPOSAL APPR DATE 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to ~ t~ ~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. GEOL AREA ?2 _C') UNIT# ~-/..¢',~"~:~ ON/OFF SHORE Y® 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N 31. Data presented on potential overpressure zones ....... Y N/ . ,,~ 32. Seismic analysis of shallow gas zones ............. Y/ 33. Seabed condition survey (if off-shore) ............. /,Y N 34. Contact name/phone for ~ progress reports [exploratory only,[ Y N 35. With proper cementin.g,,~cords, this p.p.p.p~n (A) will contain wa..,~.in .a su. itab~r~ceiving zone; ....... Y N (B) will not co. pt-'Jminate freshw/at'Jr; or cause ddlling ~/as~... Y N to s urf. ; / (C) will/[:~dt impair mech/adical integrity of the w/etfused for disposal; Y N (D) ~1I not damage,~rbducing formation orc.~pair recovery from a Y N ./,'pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERINg: ~nn~_ COMMISSION: R~~ jBgHW~ ~[~"~V~ / RNoDWJ~' CO ~ ~/~ Comments/Instructions: c:\msoffice\wordian\diana\checklist