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199-064
e e MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg . keá1' <;llcl'D~ P. I. Supervisor I t I' DATE: MaY8,~~ß.i \~,d1(q1{ FROM: John Spaulding, Petroleum Inspector SUBJECT: Location Clearances Pioneer Unit Pioneer Natural Res. The following wells in the Pioneer Unit were inspected for location clearances: Bering 03 PTD: 202-177 Baranoff 04 PTD: 202-178 Cook 01 PTD: 202180 Lowell 02 PTD: 202-179 ~~~~~~g~ ~~~ ~i~~9-064 1702-15DD PTD: 199-066 :::JGAA\lNED JUN 1 ,1 Cornhusker 04 PTD: 202-181 RL Smith 03 PTD: 202-182 DL Smith 01 PTD: 202-184 Stromberg 02 PTD: 202-183 BL T 01 PTD: 199-068 All locations were found to be in excellent shape, well graded with some small amounts of debris. I requested that the debris be cleaned up and Joe Polya Pioneer Nat. Resources rep. agreed. He will inform as to when the final cleanup has been made so that I may make one last pass over the locations. SUMMARY; I found all locations in very good condition with small amounts of tidying up to be done. Attachments: photos on CD NON-CONFIDENTIAL Well location Vine Road in off Water Well STATE OF ALASKA _ RECEIVED ALASKA aND GAS CONSERVATION COMMISSI<JI' . ('\"r" .. r WELL COMPLETION OR RECOMPLETION REPORT ANö lod005 1 a. Well Status: OilD GasD Plugged ~ Abandoned 0 Suspended D WAGD 1b. WeA~tmlrO¡¡ & Gas Cons. Comml sian 20AAC 25.105 20AAC 25.110 Development ÇJ AncHMW@lftOryD GINJD WINJD WDSPL D No. of Completions Other Service 0 Stratigraphic TestD 2. Operator Name: 5. Date Comp., Susp., or 12. Permit to Drill Number: Pioneer Natural Resources Alaska, Inc. Aband.: Aug 19, 200!;j. ,,''''''~''+. 3. Address: 6. Date Spudded: 13. API Number: 700 G Street, Suite 600 Anchorage, AK 99501 July 31,1999 50-009-20015-00 ./ 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 1354' FSL, 527' FEL, Sec 15, T17N, R2W, SM August 17,1999 1702-15DA WDW ./ Top of Productive Horizon: 8. KB Elevation (ft): 15. Field/Pool(s): Same 276 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- 569296 y- 2762483 (NAD 27) Zone- 4 4265 MD, TVD ADL 374117 TPI: x- same y- same Zone- 4 11. Depth Where SSSV Set: 17. Land Use Perm it: Total Depth: x- same y- same Zone- 4 NA NA 18. Directional Survey: Yes D No 0 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 9.625 36 J-55 Surface 675 Surface 675 12.25 550 sx class G None 7 23 CF-50 Surface 4255 Surface 4255 8.75 515 sx class G None 23. Perforations open to Production~MD.+ TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) None 2/7/2008 2175 NA 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ~I.; 5CANNELJ [lEG 1 ~ 2005 DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 3380-4080 55 bbl Type I cement squeezed below pkr. / \o\'IP 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 nnlt"It..1 ^ I nJ1.. fl.BfJA1<) , -- Form 10-407 Revised 12/2003 Cb~T~U~Dlo~ iRE~E~~L . fO f (8(tJS ~ ~4 N 28. GEOLOGIC MARKERS ~ 29. :)RMATION TESTS NAME MD< ~ TVD Include and briefly summãrize 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: ", ~ ::::n Phone: 907-343-2111 Date: JO/t7/ 0 ~ c I' INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 e e Pioneer Natural Resources Alaska, Inc. Pioneer Unit 1702-15DA-WDW Plug and Abandonment Operations Summary August 12, 2005 Inject 244 bbl of well returns from project down well. Injection pressure 1800 psi at 2.5 to 3 bpm. Casing pressure200 psi. Flush tubing with 10 bbl water. August 15, 2005 RU triplex pump on tubing to inject well returns from 1702-14CC well. Inject 100 bb1 water returns at 1880 psi, 3 bpm. Batch mix 55 bbl15 ppg Type I cement and pump down tubing at 3 bpm. Initial injection pressure 1900 psi dropped to 1600 psi after cement pumped. Drop wiper ball, displace cement with 17 bbl water at 1400 to 1500 psi rising to 1800 psi at shut in. Clean up equipment. August 16, 2005 Pressure test squeeze plug to 1250 psi. Rig up Pollard and APRS. Rlli with tubing punch to 2734 feet. Perf tubing from 2730 to 2734 feet. POOH, check gun, shots fired. RU triplex pump on tubing, no circulation at 2000 psi. Also unable to circulate down casing. RU Pollard and APRS, RIH and perforate tubing at 2650 to 2654 feet. Establish circulation down tubing and up casing. Mix and pump 102 bbl 15 ppg Type I cement down tubing taking returns out casing. Did not receive cement to surface, mix another 6 bbl cement and pump same, no cement returns, mix another 6 bbl cement and pump same, cement returns to surface. Shut in well. Clean up equipment with partial well returns water. SDFN. August 17, 2005 Dig out cellar. Entire cellar full of concrete 6 feet deep under 6 inches of surface gravel. Presume that leftover concrete from injection facility slab was poured in cellar. Spent 6 hours jack hammering concrete out of cellar. Cut off well, cement to surface in all casings. August 18, 2005 Chuck Sheve of the AOGCC inspected 1702-14CC well for P&A. August 19, 2005 Welded marker plate on well. Backfill to be completed upon removal of surface equipment. Disposed of 110 bbl well returns (water) from 1702-15DA- WDW well via Alpine Septic Service and AWWU. - 1 - Pioneer Natural Resources Alaska, Inc. 1702-15DA-WDW Plug and Abandonment Photos Photo 1: 1702-15DA-WDW cellar excavation. - 2 - Photo 2: 1702-15DA-WDW concrete sheath. - 3 - Photo 3: 1702-15DD-WDW well cut off. -4- Photo 4: 1702-15DA- WDW well with marker plate installed. - 5 - Pioneer Unit 1702-15DA-WDW Final Well Schematic II 1702·15DA WDW API 50-009-20015 r Sec 15 Pioneer Natural Resources Alaska, Inc. wp 17N Rn9 2W Size Weight Grade Thread Matanuska,Susitna State Alaska Casing 9.62S 36 J-SS Pioneer Unit Country USA :Eii 7 23 J-SS 8rd 2-7/8 8rd 2 t=~ 60 50 @ 4 spf an 3480 35 Perfs 3480-3515 @ 4 H 3380 40 Perfs 3380-3420 @ 4 spf and 23g, SQU 2743 1.1 2.875 2.250 Seat Nipple Jlsurface F ~tedpaCke' Tool in 7 inch casing II cuttoff 5 feet below ground level. I=± = =t ===i = t t== I Created b ' STG on 3/23/03 Modified b JRM on 14-se y y p-05 ) ) tqq-"o~4 Pioneer Natural Resources Alaska, Inc. Plug and Abandon Procedure Pioneer Unit 1702-15DA wnw Well Revision 1, August 5, 2005 The 1702-15DA WDW well was drilled in 1999 by Ocean Energy for the purposes of water disposal well. The well has a 13-3/8 inch conductor set at 35 feet, 9-5/8 inch surface casing set at 675 feet and 7 inch production casing set at 4237 feet. Both the 9- 5/8 and 7 inch casing strings have been cemented back to surface. Inside the production casing, 2-7/8 inch tubing is hung from surface with a packer at 2751 feet. The well is also perforated at various intervals from 3380 to 4080 feet. Attachment 1 shows the current 1702-15DA WDW well diagram. Pioneer Natural Resources Alaska, Inc. (Pioneer) proposes the following P&A procedure to plug the well in accordance with AOGCC regulations. The proposed final 1702-15DA WDW 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 positive pressure on tubing and lower monitoring pressure on tubing/casing annulus. Check for pressure on 9-5/8x7 inch annulus, bleed off any pressure. Expect no pressure on 9-5/8 x 7 inch annulus since the 7 inch casing has been cemented to surface. 4. Rig up high pressure lines on casing wing valve and test casing to 1500 psi to verify mechanical integrity. Rig up same on tubing and verify ability to inject into perforations and establish injection pressure. 5. Mix and pump 55 bbl, 15 ppg, Type I cement down tubing and squeeze perforations below packer. Drop a foam wiper ball and displace cement with 16 bbl water. Clean up equipment and WOC. 6. Test squeeze job to 1100 psi. 7. Rig up slickline unit for tubing punch. RIH and punch tubing with minimum 4 holes at 2740 feet MD. 8. Mix and pump 102 bbl 15 ppg Type I cement down tubing and up annulus to fill well with cement. Clean up equipment. WOC. 9. 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 1702-150A wow P&A procedure rev 1.doc - 1 - SC/\NNEC AUG ì) 9 2005 ) ) 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. 10. Weld on well ID marker plate (1/4" x 24" x 24") with the following information bead welded on plate: Pioneer NRA APD: 199-064 Pioneer Unit 1702-15DA-WDW API: 50-009-20015-00 Backfill well excavation and grade for positive drainage. Perform complete site inspection immediately after P&A operations if AOGCC inspector is available. 1702-150A wow P&A procedure rev 1.doc - 2 - - e MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg, P. I. Supervisor ...-----, , /" ~ _'..... '1/, ..___" '..: /~.-"" I ' ,¡"" -"'"7 '¡ ; ::] j) 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 170215DA-WD PTÞ# 1Q9..0U 1702 1500 PTO# 199-066 BL T-01 PTO# 199-068 Thursday, AUQust 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 1500 .JPG BL T-01. JPG cC A !I.~~~. f';;;~·" ~;-Jr~,¿-'t..n~l, "..~L._.", r tJ: 1 2DD~ .", t:"; ~~ {-f ,__ Willow Fishhook # t Cement to Surface Plate 2 to Surface I Cement Marker Plate 3 @iTiÍ'iTlErr'J'irÞIIY,! 'l\\ ~ ~ ~ rr,;·r& /.' @ U IJ1J u Lb UV u If\ll=ï Lrü 6i) lfu W AI¡ASIiA OIL AlÐ) GAS / CONSERVATION COltDllSSION FRANK H. MURKOWSKI, GOVERNOR 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Joe Polya Senior Staff Drilling Engineer Pioneer Natural Resources Alaska, Inc. 700 G Street, Suite 600 Anchorage, Alaska 99501 1.... ¡¡Lc l?t~,!...C~ti¢ '1 Re: Pioneer 1702-15DA-WDW Sundry Number: 305-204 Dear Mr. Polya: , E"D-\ H'l '11 ;(~ '200'5 SÇANN ',J U _ t.:, ~. 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 liday or weekend. A person may not appeal a Commission decisi Superior Court unless rehearing has been requested. ,."- (, S· c ely, DATED thiS~ of July, 2005 Encl. ( July 20, 2005 RECEIVED JUL 2 6 2005 Alaska Oil & Gas C ons. Commission Anchorage 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 - 1702-15DA-WDW Well Plug and Abandon Dear Mr. Aubert: Attached is the 10-403 form requesting approval to Plug and Abandon the 1702- 15DA-WDW 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, ~~\?2v foe Polya Sr. Staff Drilling Engineer Pioneer Natural Resources Alaska, Inc. 700 G Street, Suite 600 Anchorage, AK 99501 o IG!NAL C(/J- 7 .,. 71 ,.()~ / STATE OF ALASKA -4 /27 0 ALAS~ JIL AND GAS CONSERVATION COMMIS'-..JN /- APPLICATION FOR SUNDRY APPROVAL / 20 MC 25.280 Suspend U Operational shutdown U Repair well 0 Plug Perforations 0 Pull Tubing 0 Perforate New Pool 0 4. Current Well Class: Abandon 1J Alter casing 0 Change approved program 0 2. Operator Name: 1. Type of Request: Pioneer Natural Resources Alaska, Inc. 3. Address: 700 G Street Suite 600 Anchorage, AK 99501 7. KB Elevation (ft): 276 ft KB (11' AGL) 8. Property Designation: Private 11. Total Depth MD (ft): 4265' MD Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): 3380-4080 Total Depth TVD (ft): 4265' TVD Length n/a 35 feet 677 feet n/a 4245 feet n/a Development Stratigraphic \<4 \..) , \'" I I (.. , I ¿.ðO ~ RECEIVED JUL 2 6 2005 A~Ivë~& Gas Con~t~ffl'ssion Stimulate 0 Time Extension 0 Anchorage Re-enter Suspended Well 0 5. Per~to Drill Number: Exploratory 0 199-064 Injection Order 20 Service / 0 6. API Number: 50-009-20015-00-00 / Perforate U o o 9. Well Name and Number: 1702-15DA-WDW / 10. Field/Pools(s): Pioneer Unit (610036) PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 4123' MD 4123' TVD Size n/a 12.750 inches 9.625 inches n/a 7.000 inches n/a Perforation Depth TVD (ft): 3380-4080 Packers and SSSV Type: Arrow Set AS1-X Plastic Coated Packer 12. Attachments: Description Summary of Proposal U Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Date: 2-7/8 6.4 PPF Packers and SSSV MD (ft): Packer set @ 2751 ft. md. 13. Well Class after proposed work: Exploratory 0 Development 15. Well Status after proposed work: 7/31/2005 Oil 0 Gas 0 WAG 0 GINJ 0 MD n/a 49-1eet ,I ,I t'~,~'feet ~afeet (--~/a Tubing Size: Plugs (measured): N/A TVD Burst n/a n/a 46 feet n/a 688 feet 3520 psi n/a n/a 4255 feet 4000 psi n/a n/a Tubing Grade: J-55 o Plugged WINJ 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 "~a....". _ Phone 907-343-2111 Date 7/'ZG/o~ ,. . I - \ COMMISSION USE ONLY Junk (measured): NONE Collapse n/a n/a 2020 psi n/a 3110 psi n/a Tubing MD (ft): 2745' MD '"' r71.,¡ <'" Service ~ .,/ o Abandoned o WDSPL o o Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 30 !!::t.-... ;Jo c..r Location Clearance ~ Plug Integrity 0 Other: BOP Test 0 40'1. ~ .... ~ Form 10-403 Revised 11/2004 Mechanical Integrity Test 0 COMMISSIONER RBDMS BFl JUL 2 8 2005 APPROVED BY THE COMMISSION Date: OR\G\NAL 1ft/I Submit in Duplicate ~' I~ Pioneer Natural Resources Alaska, Inc. Plug and Abandon Procedure Pioneer Unit 1702-15DA WDW Well The 1702-15DA WDW well was drilled in 1999 by Ocean Energy for the purposes of water disposal well. The well has a 13-3/8 inch conductor set at 35 feet, 9-5/8 inch / surface casing set at 675 feet and 7 inch production casing set at 4.237 feet. Both the 9- 5/8 and 7 inch casing strings have been cemented back to surface:" Inside the production casing, 2-7/8 inch tubing is hung from surface with a packer at 2751 feet. The well is also perforated at various intervals from 3380 to 4080 feet. Attachment 1 shows the current 1702-15DA WDW well diagram. Pioneer Natural Resources Alaska, Inc. (Pioneer) proposes the following P&A procedure to plug the well in accordance with AOGCC regulations. The proposed final 1702-15DA WDW 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 positive pressure on tubing and lower monitoring pressure on tubing/casing annulus. Rig up high pressure lines on casing wing valve and test casing to 2000 psi to verify mechanical integrity. Rig up same on tubing and verify ability to inject into perforations. Check for pressure on 9-5/8x7 inch annulus, bleed off any pressure. f"/ Expect no pressure on 9-5/8 x 7 inch annulus since the 7 inch casing has been cemented to surface. Rig down pressure test lines. 4. 5. 6. Rig up slickline unit for tubing punch. RIH and punch tubing with minimum 4 holes at 2740 feet MD. Rig up cementing lines on tubing/casing annulus and second line on tubing. Rig tubing connection on a T to allow swapping lines easily as described below. Verify ability to circulate down annulus and up tubing (Le. tubing and annulus pressures should be the same after tubing punch) and reconfirm ability to inject into perforation~s'ì Mix and pump 8~/hbl, 15 ppg, Type I cement down annulus with tubing shut in and simultaneo . Sly inject annular fluids into perforations below packer. Shut in annulus whe;g6 bbl pumped. Quickly swap pump line over to tubing and inject an additiona 7j. bbl of cement down tubing to squeeze perforations below the tubing and ltí tubing with cement. 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. 1702-15DA WDW P&A procedure.doc - 1 - 7/19/2005 11 :07 AM ( 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: 199-064 Pioneer Unit 1702-15DA-WDW API: 50-009-20015-00 Backfill well excavation and grade for positive drainage. Perform complete site inspection immediately after P&A operations if AGGCC inspector is available. 1702-150A WOW P&A procedure.doc - 2 - 7/19/2005 11 :07 AM Attachment 1: Pioneer Unit 1702-15DA-WDW Current Well Schematic PBTD 4123 Well 1702·15DA WDW API 50-009-20015 I Qtr/Qtr See 15 Pioneer Natural Resources Alaska, Inc. Twp 17N Rng 2W Size Weight Grade Thread Depth County Matanuska,Susitna State Alaska Casing Field Pioneer Unit Country USA Casing 7 23 J·55 8rd Tubing 2-7/8 6.4 J·55 8rd 2733 No. I Depth I Length I 00 10 Description 1 4060 20 Perfs 4060-4080 @ 4 spf and 23 gram charges 2 3940 60 Perfs 3940-4000 @ 4 spf and 23 gram charges 3 3700 50 Perfs 3700-3750 @ 4 spf and 23 gram charges 4 3480 35 Perfs 3480-3515 @ 4 spf and 23 gram charges 5 3380 40 Perfs 3380-3420 @ 4 spf and 23 gram charges 6 2743 1.1 2.875 2.250 Seat Nipple 7 2740 7 6.125 3.000 Arrowset AS1-X Plastic Coated Packer 8 1822 DV Tool in 7 inch casing 6 7 5 4 3 2 Created by STG on 3/23/03 Modified by JRM on 7/19/05 if I( Attachment 2: Pioneer Unit 1702-15DA-WDW Proposed Final Well Schematic 50-009-20015 Pioneer Natural Resources Alaska, Inc. PBTD 4123 9 Well 1702·15DA WDW API Qtr/Qtr Sec 15 Twp 17N Rng 2W County Matanuska,Susitna State Field Pioneer Unit Country No. I Depth I Length I OD 1 4060 20 2 3940 60 3 3700 50 4 3480 35 5 3380 40 6 2743 1.1 2.875 7 2751 7 6.125 8 1822 9 Surface 6 7 5 4 3 2 Created by STG on 3/23/03 Size Weight Grade Thread Depth 36 j55 23 J-55 8rd 6.4 J-55 8rd Description Perfs 4060-4080 @ 4 spf, 23 g, SQUEEZED Perfs 3940-4000 @ 4 spf and 23 g, SQUEEZED Perfs 3700-3750 @ 4 spf and 23 g, SQUEEZED Perfs 3480-3515 @ 4 spf and 23 9, SQUEEZED Perfs 3380-3420 @ 4 spf and 23g, SQUEEZED 2.250 Seat Nipple 3.000 Arrowset AS1-X Plastic Coated Packer DV Tool in 7 inch casing Well cuttoff 5 feet below ground level. Alaska USA Casing Casing Tubing 9.625 7 2-7/8 2733 ID Modified by JRM on 7/19/05 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Randy Ruedrich DATE: September 10, 2003 Commissioner (~I' "~7-7 ~i~//l~l~:/"tc;~ SUBJECT:EvergreenMeChanical Integrity Test THRU: Jim Regg P.I. Supervisor Pioneer Unit FROM' Chuck Scheve Petroleum Inspector NON- CONFIDENTIAL Well 11702-15DA P.T.D. I 99-64 Notes: WellI P.T.D.I Notes: WellI P.T.D.I Notes: WellI P.T.D.I Notes: WellI P.T.D.I Notes: Packer Depth Pretest Initial 15 Min. 30 Min. ITypelnJ. I N I T.V.D. I~o I Tu~i,gl ~o4o 11~oo I~o~o I~o~o Ilnte~all W Type testI P I Testpsi[ 1500 I CasingI 190 I 1640 I 1640 I 1640I P/F I P IType Inj. Type test IType I nj. Type test IType Inj. Type test Type test Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER INJ. N -- NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to Evergreen's Pioneer Unit and witnessed the post workover MIT on well 1702-15DA. The pretest tubing and casing pressures were observed and found to be stable. The pressure test was then performed with this well demonstrating good mechanical integrity. M.I.T.'s performed: 1_ Number of Failures: 0 Attachments' Total Time during tests: 2 hours cc: MIT report form 5/12/00 L.G. ,~.(0A~NED 007 ~L ~ 2:003 MIT Pioneer Unit 9-10-03 CS.xls 9/15/2003 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1, Operations Performed: Abandon [] Suspend [] Operation Shutdown [] Perforate [] Variance [] Annular Disposal [] Alter Casing [] Repair Well [] Plug Perforations [] Stimulate [] Time Extension [] Other [] Change Approved Program [] Pull Tubing [] Perforate New Pool [] Re-enter Suspended Well [] 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: Evergreen Resources Alaska Corp. Development [] Exploratory [] 199-064 Injection Order 20 3. Address: P.O. Box 871845 Stratigraphic [] Service [] 6. APl Number: Wasilla, AK 99687 50- 009-20015-00 7. KB Elevation (ft): 276 ft KB (11' AGL) 9. Well Name and Number: 1702-15DA WDW 8. Property Designation: Private 10. Field/Pool(s): Pioneer Unit (610036) 11. Present Well Condition Summary: Total Depth measured 4265' feet true vertical 4265' feet Plugs (measured) N/A Effective Depth measured 4123' feet Junk (measured) N/A true vertical 4123' feet Casing Length Size MD TVD Burst Collapse Stru ctu ral N/A N/A NIA N/A NIA N/A Conductor 35' 12-3~4 46' 46' NIA N/A Surface 677' 9-5/8 688' 688' 3520' 2020' , , :, , . : Production 4255' 7 4255' 4255' 4000 3110 , Liner N/A N/A N/A N/A N/A N/A /, ~ :~ ~:.;. ,. ~ ii~' .~ ,-.; Perforation depth: Measured depth: 3380'-4080' , True vertical depth: 3380'-4080' Tubing: (size, grade, and measured depth) 2-7~8 J-55 2742' Packers and SSSV (type and measured depth) AS!-X 2751' 12, Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: N/A N/A -400 0 1814 Subsequent to operation: N/A N/A -600 0 1800 14, Attachments: 15, Well Class after proposed work: Copies of Logs and Surveys Run N/A Exploratory [] Development [] Service [] 16. Well Status after proposed work: Daily Report of Well Operations XXX Oil [] Gas [] WAG[] GINJI--I WIN J[] WDSPLE~ 17, I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 303-187 C:.nnfnnt ~hnn~ ~nnlinrHi Printed Name Sh.a~'~Gaqliardi __ ~ Title Petroleum En.qineer Signature .. Phone 907-355-8569 Date 8/21/03 Form 10-404 Revised 2/2003 ~$ BFL Daily Completion Report .,,,,o,,.o 144 ...,. J07/16/03 Elld I~/~/aoo~ Supervisor IT,out J w,,,, 1702-15DAWDW No 14 .., 50-009-20015-00 Operator IEvergreenResourcesAlaska .,o,dlPionee, ~tr/~tr NE/SE s~ 15 mw~ 17N Rng 2W lcou.ty IMat-Su sat. Alaska Cou.t~ USA Co.tr. ctor EWS # 9619 Cur~.nt Act~,,~ Prepare to Pull Packer 24hr Fo=..tI Prepare to Clean to PBTD L~,O~ ,, yro.,($) $7,100.00 wo,, To,,,, (,, I $287,529.00 lAcclden, (yin, INo L.t S,,,,~ ,,,,t,,, ,,t, I 6-02-03 Start End Duration Actlv~ .7. -_!._5:.-0 3__~ p_.r?_a._d_p!a_stj c_, B_u_..E _.w_ S.._u n i~t ~_96._1_~ 0.7._0_0 ..... 0~7_3_? ........ _!!~ ....................... _W_ar.m_u.~_.e_q..!p_._m_e_.n.!~._F~.e.~.r__e_.!.o__~!p_p.!?_~p_.~gP_ _0.73_0 !0.800 .1/2 ........... R U_.c. a__m_er.?_a_nd _& ~l_u br_!_ca!_o_ .r., ) ~s. ta~l! b_a_c_k, pr~s.s..u_re.v.alye .in.t°_ t.b_g..ba~.g? 08-00 1000 2 ........... Re _m_0..v_ed a_~apte[_.fla. 9g_e,. & _X. ma_s_ !?ee. v_a!v_e_:. !nstallgd. BQ?.. P[es_s_.u_re.test S_.o.p.tQ.2§0O psL~held. OK.. ! 0o_o_. :.i.!-0..0_ .... ! ............................. P..u!!e.d_~_a_c_.k.. p?..s__s _u..r__e_v? I__v_ _e_ f_0_r.._m_ __t ~ g_h~9. _n g_e_r_..._F I_o_we d__w. e!!_i_n_t_o__.fl_ 0..w__b.a_c_k. !.a_n_k ._ ) ! _0_0 ..... ! !._3~ ..... !.!.!_2 .U.n_s_e?_!_A_Sj~x.P_a_c__ke__r.~t_~_2_7_..5.1_: !..!.30 ...... !.2_.-00- ....... )/2 ]_2._00_ .......... !,.4..°_.~ ...... !~ .................................... , ,R_e_~ a_i~re_d_e I_e_ .v a_ !. .°. _r_s '__ ..!.~00 ............ .153._0 ......... ! .!_/..2 ........................... F.i_n!§ h_~_d__T0_H_.~/_t_o_.!~!2!...87. j~.._ 2_.~ (_81;.!b.g- .~...A_.~] ]530 !.7_00 !... !!2 ,!707 ....... ! .9._0~ ........ ~ ,.R,~ ,.~EW_,.s.., _u,.n.. it~..4.0.,,2!,o_. 2_.-C8' "._.x_7. ;i. a_,.n_n._uJ~ s- a_,n..d., r..e.,.v.9,r,~.e,_c!r~.u!.a_t,e. !.900 2030 ! ]/~ ..L,D 4~r..jt.s... ~. ~(81.i. COST ESTIMATE; R.[~ Misc. $500.00 ,,vv.,~!e[~ $4,ooo.o.~.~_o , , .......... Ver 1,0.~t-1/8-28-99 Report No 45 Begin 107/17/03 Daily Completion Report End 7/17/2003 we. 1702-15DAWDW No 14 APl 50-009-20015-00 t ontractor~ IEWS ~ 9619 c .... tAct~vW Prepare to Pull Packer ~ I I~'`'yT°a''', $6,100.00 w. To,, (,, 1 I $293.629.00 Supervisor Trout Operator IEvergreen Resources Alaska F~o~d [Pioneer Mat-Su ls",o IAlaska co,..~ USA 24hrF .... t Prepare to Clean to PBTD IAcc'd""t(y'") NO Last Safety Meeting Date { 6-02-03 Start End Duration Activity 0700 0715 1/4 !0 !!2hr S!T.P.800` p~si_.~ _F_l_?e_.d__p[e_ss_ure__°_ff tbg !o.!a_nk.. 07. ! 5 0.83.0 ...... !_ _1_/~ .............. F!~!~.hed~ 08.30 ..... .0.945 !!(4 P~. _A_rr0_w..A$!.x Pa_Ck~.r_&_TIH W( 2 7(8'_' t_bg as f..°!!.°_WS: 87 jts 2 7/8" 6.5# EUE J-55 tbg. 2730.59 i i.' '.'ii'.i .,_ ii !i.i¢i !0:' X !72.7(8" 2739.94 KB bottom of packer @ 2751' in neutral position. 1130 1200 1/2 Install surface plug in tbg hanger & strip off BOP. 1200 '. '!1.2S0' 1230 !30,0 .... 1.!2 Pres~?e..up .! 300 ......... 1~00, ~1 ~.D,,.,EW,S {Note, tbg hanger will need to be removed so slack off tbg can be obtained to unseat ^Slx packer) .......................................................... i ! ! ............................................................................................................................................................................................................... COST ESTIMATE; ,;~' . $1,500.00 : ~.U.P,..e.~igi,.°,,,n Misc. $500.00 ~!~[~ $3,5oo,o~0 IOT^L ........ $~,100.00 -- Vet 1,0 jjt-1 / 8-28-99 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Randy Ruedrich ''~ Commissioner P.I. Supervisor ' / FROM: Chuck Scheve Petroleum Inspector NON- CONFIDENTIAL DATE: June 17, 2003 SUBJECT: Mechanical Integrity Test Evergreen Pioneer Unit Packer Depth Pretest Initial 15 Min. 30 Min. We,,llT02-~SDAIType,nj.I s I T.V.D. I 2740 I Tubingl 1700 I 1700 I 1700 I 1700I,nterva, l' ~ P.T.D.I 99-64 ]TypetestI P ITestps. il 1500 I Casingl 25 I i5601 ~5601 ~560I P/FI_P Notes: ,nj.! N I T.V.D. {2566 I Tubing[ 350 [ 350 I 350 [ 350 [,ntervail" I WelII~702-~4CCIType!estl P ITestPsil i500 I Casingl 0 I ~6001 ~6001 ~6001 P/FIE P.T.D.] 99-65 ]Type. Notes: "WellI P.T.D.I Notes: WellI Type Inj. P.T.D.I Notes: P.T.D.I Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during WorkoVer O= Other (describe in notes) Test's Details I traveled to Evergreen's Pioneer Unit and witnessed the initial MIT on wells 1702-14CC and 1702-15DA. The pretest tubing and casing pressures were observed and found to be stable. The pressure test was then performed with both wells demonstrating good mechanical integrity. M.I.T.'s performed: 2 Number of Failures: O Attachments: Total Time during tests: 3 hours cc: MIT report form 5/12/00 L.G. $CZ-~N~E£,~ AUG 0 ,~- 2003 2003-0617_MIT_Pioneer_15DA_cs.xls 7/9/2003 RESOURCES (ALASKA) CORP. A Subsidiary of Evergreen Resources, Inc. July 9, 2003 Ms. Sarah Palin Dr. Randy Ruederich Mr. Daniel Seamount Commissioner Alaska Oil and Gas Conservation Commission 333 W. 7th Ave #100 Anchorage, Alaska, 99501-3539 RE: Sundry Approval (Form 10-403) Pioneer Unit - DL Smith #1, Stromberg #2, RL Smith #3, Cornhusker #4, Cook #1 and 1702-15DA Dear Commissioners Palin, Ruederich and Seamount: Attached are the 10-403 forms for the following wells. The proposed workover operations will cons, isf~ pump changes and running cement bond logs on two wells squeezed wa the rm ~n head. Well Work Over Description RL Smith- Down size pump and Run CBL DL Smith- Downsize pump Stromberg- Downsize pump Cornhusker - Upsize pump and run CBL Cook - Downsize pump 1702-15DA - Clean to PBTD / If you have any questions, please feel free to contact me at 907-355-8569 or shaneg~evergreengas.com.. Sincerely, Shane Gagli~~ Petroleum Engineer $CANN 'JUL i 6 2003 JUL 0 9 2OO3 0if ~'' 1075 Check Street, Suite 202 · Was#la AK 99654 P.O. Box 871845 · Was#la, AK 99687 · TEL 907,357,8130 · FAX 907.357,8340 Jul 10 03 08:11a DH 907.357.83~0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 .,, 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Perforate [] Variance [] Annular Disposal [] Alter Casing [] Repair Well [] Plug Perforations [] Stimulate [] Time Extension [] Other [] Change Approved Program [] Pull Tubing [] Perforate New Pool [] Re-enter Suspended Well [] 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name.:. E..ver.green Resources Alaska Corp. Development [] Exploratory [] "" 199.064 Injection Order 20 3. Address: P.O, Box 871845 Stratigraphic [] Service [] 6. APl Number: Wasilla, AK 99687 50- 009-20015-00 7. KB Elevation (fi): 276 ft KB (11' AGL) 9, Well Name and Number: 1702-15DA 8, Property Designa't'i(~n: Private 10. Field/Pool(s): Pionee~'Unit (610036) 11. PRESENT WELL CONDITION SUMMARY T°tal DePth MD (ft):4265' MD IT°tel Depth TVD (ft): 14265' TVD Effective Depth MD (ft):4123, MD Effective Depth 'l'VD(ft):4123 MD ..... 'Piugs (measured)"IN!A Ounk"imeasured):NiA Casing Length Size MD TVD Burst Collap~e -- Structural NIA N/A NIA NIA NiA NIA ,, Conduclor 35 12-314 46 46 N/A NIA Surface 677 9-518 688 688 3520 ...... 2020 Interm ed ia te NIA N/A NIA NIA N/A NIA Prod uction 4255 7 4255 4255 4000 3110 · , Liner N/A N/A NIA NIA NtA NIA 3380-4080 ..... .3.3_8.0-4080 2-7/8 6.4 ppf J.:55 2745' Packers and SSSV MD (ft): Packers and SSSV Type: N/A Arrow Set ASI-X 12. Attachments: Description Summary of Proposal [] 13, Well Cfass after proposed work: Detailed Operations Program [] BOP Sketch [] Exploratory [] Development [] Service [] 14. Estimaled Date for 15. Well Status after proposed work: ,C.o. mmencing Operations: 22 July 03 ............. Oil [] Gas [] Plugged [] Abandoned [] 16. Verbal Approval: Date: WAG [] GINJ [] WINJ [] WDSPL [] Commission Representative: , , .... 17. I hereby codify that the foregoing is true"a~ correct to the best of my knowledge. Contact ShaneCa_~iia~dL ......................... Printed Name Sha~e Ga(~liardi ~ ~/"'-"% Title P~!ro!eum En.qineer Signature J~ ~ Phone 907.355.8569 Date 7/3103 ..... ~ .... Commission Use Only ................. I Sundry Nurnber:~~ .t 8~ Conditions of approval: Notify Commission so that a representative may witness Plug Integrity [] BOP Test I~ Mechanical Integrity Test [] Location Clearance [] Approved ~y: . . OUUlSS~ONE. TH~ couM!,,sslo.' Date: Form 10-403 Revised 2/2007 % Sub~Y ~ Clean Out Procedure Pioneer Unit: 1702-15DA WDW APl: 50-0009-20015 Section 15 Township 17 North Range 2 West Matanuska Susitna Borough, Alaska Elevations: GL: 265 ft KB: 276 ff (11 ff AGL) Objective: Replace existing 2-7/8" tubing and lock-set packer with 3-1/2" coated tubing and plastic coated AS-lX Aero-set packer, perform step rate injection test to determine maximum injection pressure and perform mechanical integrity test (MIT) to put pump on line. History: This well was initially drilled by Ocean Energy in 1999. EWS treated all existing and new perf intervals in this well using a borate cross link gel system in Feb 2003. Preparation: -1~t'5 "' 12~ I 1. AOGCC: Contact Winton Aubert (907-2-~. 2. Tanks: Two flow back tanks are currently on location. 3. Water: If well control incident occurs, mobilize both 80 bbl water trucks from Evergreen yard and use fluid on location as the source of kill fluid. 4. Pumping Services: EWS cement unit will be used if the well needs to be killed 5. Haul Tubing: Haul 130 jts 3-1/2" plastic coated tubing to location. Spill Prevention: Alaska Department of Environmental Conservation has strict regulations regarding spills. All equipment will have plastic liners underneath them. Liners will be run around wellhead. A transfer pump will be used to transfer water from the cellar to the flow back tanks for later injection. Casing ~nd Tubin Data: Size Weight ID Drift Collapse Burst Yield Capacity Capacity (in) (ppf) (in) (in) (psi) (psi) (klbs) Bbls/ft Ft/bbl Tubing 2-7/8" 6.5 2.441 2.347 5760 5450 99.7 0.005794 172.765 Casing 7" 23 6.366 6.241 2616 3488 0.03937 25.401 Annulus 2-7/8 to 7 ..... 0.03134 31.910 Procedure Clean Out and Injection Test 1. MIRU EWS Rig #9619 and Cmt unit 402. a. Ensure that rig is parked on plastic and sump is created around well head. 2. NU and pressure test 3000 lb manual BOP to 3000 psi as per AOGCC. a. Cameron on location to service tbg hangar. 3. RU sump pump to pump water from cellar to flow back tank. 4. POOH w/2745' 2-7/8 tbg and 7" Arrow set AS1-X packer. 5. TIH w/2-7/8 tbg and clean sand to 4123'. *' 6. POOH w/2-7/8 tbg and PU 7" AS1-X packer. 7. TIH w/2-7/8 tbg and 7" AS1-X packer. Attempt to set packer @ 3300'. If packer will not hold at that depth, move packer to 2745' and set. 8. Perform injection test to ensure packer seat. a. 4 BPM for2 hours 9. MIT 10. RDMO EWS. Current WelIQtrlQtr 1702-15DAWDWsec-,..'-EGE_- ==__ Twp 17N Rng 2W Size Weight Grade Thread Depth County Uatanuska,Susitna State Alaska Casing Field Pioneer Unit Country USA Casing 7 23 J-$5 8rd Tubing 2-7~8 6.4 J-55 8rd 2733 No. I Depth I Length I OD I ID Description 1 4060 20 Perfs 4060-4080 ~ 4 spf and 23 gram charges 2 3940 60 Perfs 3940-4000 ~ 4 spf and 23 gram charges 3 3700 50 Perfs 3700-3750 ~ 4 spf and 23 gram charges 4 3480 35 Perfs 3480-3515 ~ 4 spf and 23 gram charges 5 3380 40 Perfs 3380-3420 ~ 4 spf and 23 gram charges 6 2740 7 6,125 3.000 Arrowset AS1-X Plastic Coated Packer PBTD 4123 Created by STG on 3/23/03 Modified by STG on 7/8/03 Proposed · QtrlQtr Sec 15 ~V I(~1~1( I~1~ "='= ~ Twp 17N Rng 2W Size Weight Grade Thread Depth County Matanuska,Susitna State Alaska Casing Field Pioneer Unit Country USA Casing 7 23 J-55 8rd Tubing 2-718 6.4 J-55 8rd 2733 No. I Depth I Length I OD I ID Description 1 4060! 20 Perfs 4060-4080 (~ 4 spf and 23 gram charges 2 3940 60 Perfs 3940-4000 (~ 4 spf and 23 gram charges 3 3700 50 Perfs 3700-3750 @ 4 spf and 23 gram charges 4 3480 35 Perfs 3480-3515 (~ 4 spf and 23 gram charges 5 3380 40 Perfs 3380-3420 (~ 4 spf and 23 gram charges 6 2740 7 6.125 3.000 Arrowset AS1-× Plastic Coated Packer PBTD 4123 Created by STG on 3/23/03 Modified by STG on 7/8/03 A OGCC Memorandum Date: 3/28/2003 To: From: Subject: PTD 199-064 (Pioneer Unit 1702 15DA-WDW) Jim Regg, Petroleum Engineer '~2~e2'[x~ Pioneer CBM Project - Well 15DA-WD (PTD 199-064) Shane Gagliardi (Evergreen) called and left message indicating that Evergreen is intending to move back onto Well 15DA-WD at Pioneer Unit. I returned call to Shane today (-9:00 am). Evergreen previously ran a lock set packer and tubing string in the water disposal well; they are happy w/performance of the well; now planning to do step rate and sustained rate tests. They will swap packer and tubing for more permanent installations (he indicated plastic coated tubing). Intent of his call was to notify us of planned work. I questioned if work was covered under existing sundry approval; he indicated all but the equipment change. Advised that I will confirm if revised sundry is needed or if work can be addressed in subsequent 10-404. Work will start work tomorrow and is expected to take a 1-2 days. Re: Thaqk you for the clarification Subject: Re: Thank you for the clarification Date: Thu, 06 Mar 2003 17:04:06 -0900 From: Jim Regg <jim_regg~admin.state.ak.us> Organization: AOGCC To: John Tanigawa <JohnT~EvergreenGas.com> John - Tom and I discussed this further and think we have a better (more accurate) response for you, as follows, per our discussions today regarding the Pioneer 1702-15DAWater Disposal Well: Max injection pressure DIO 20 includes statement in the conclusions that the disposal injection operations will be conducted at rates and pressures below this required to fracture the confining zones. There is no specifc rule that establishes a max pressure. Statewide regulations I quoted really only apply to a casing test where you do not have open perfs. In your sitation the limit is bound by that pressure that would fracture the confining zone (conclusion #6 in DIO 20); the mechanical limits would be burst of injection string (tubing) and the pressure that would unseat your packer. Question I would pose to you then is what frac modeling of the confining zone has been performed? This is also where the well integrity and surveillance requirements play a role per Rules #4 & #5. Packer Setting Depth Again from DIO 20, the packer setting depth was stated (by Ocean Energy) to be 50 feet above the top of the perfs or "uppermost disposal interval", whichever is shallowest. The uppermost disposal interval is the Tyonek Formation strata that are common to and correlate with the interval below 2,790 feet in the BLT #1 well (DIO 20, Rule 1). Jim Regg John Tanigawa wrote: Jim,Thank you and Tom M for clarifiying the maximum surface pressure and the upper most injection interval for th 1702-15DA WDW. Here is my e-mail address.Thank you Jim.John T. Jim Regg <jim_regg~admin.state.ak.us> Petroleum Engineer AOGCC Administration 3/7/2003 7:06 AM CL II WELL INJECTION EVENT REPORT TO MEET REQUIREMENTS OF 20AAC 25.432 Shane Ga.qliardi 29 March 2003 1900 Name of Person Injecting Fluid (Print) Date (Day/Month/Year) Time Injection Event Began Time Disposal Rate (BPM) Disposal Volume TUBING PRESSURE CASING PRESSURE (Min): Per Time Step Cumulative (PSIG) (PSIG) (bbls) (bbls) Start of 0 0 0 0 1500 Injection +30:00 1 BPM 30 30 100 1500 +60:00 2 BPM 60 90 800 1500 +90:00 3 BPM 90 180 1400 1500 +120:00 4 BPM 120 300 1850 1500 +150:00 5 BPM 150 450 2000 1500 +180:00 5.5 BPM 165 615 2150 1650 +210:00 5.5 BPM 165 780 2250 1700 +227:00 5.5 BPM 93 873 2000 1700 I hereby certifv...tl:~at the fore~oin, g-is.t.r, ue, and correct to the best of my knowledge Title Petroleum En.qineer Date 4/8/03 - CLASS II WELL INJECTION EVENT REPORT_ ~,, Shane Ga.qliardi 27 February 2003 1700 Name of Person Injecting Fluid (Print) Date (Day/Month/Year) Time Injection Event Began Time Disposal Rate (BPM) Disposal Volume TUBING PRESSURE CASING PRESSURE (Min): Per Time Step Cumulative (PSIG) (PSIG) (bbls) (bbls) Start of 0 0 0 0 1100 Injection +85:00 3.0 BPM 400 400 1500 1500 I hereby certify/J/ha,,t the foregoing is tr. ue,.and correct to the best of my knowledge Signed ___,~'~:'~'~'--~.~_,~~'~ .... Title Petroleum En.qineer Date 2/28/03 .. ECTION EVENT REPORT TO MEET REQUIREMENTS OF 20AAC 25.432 Shane Ga.qliardi 24 February 2003 1700 Name of Person Injecting Fluid (Print) Date (Day/Month/Year) Time Injection Event Began Time Disposal Rate (BPM) Disposal Volume TUBING PRESSURE CASING PRESSURE (Min): Per Time Step Cumulative (PSIG) (PSIG) (bbls) (bbls) Start of 0 0 0 0 680 Injection +15:00 1.2 BPM 15 30 375 680 +30:00 1.2 BPM 22 52 570 680 +45:00 1.2 BPM 18 70 630 680 +60:00 1 BPM 15 85 680 680 +75:00 1 BPM 15 100 700 750 +90:00 2 BPM 30 130 1090 750 +105:00 2 BPM 30 160 1150 830 "~ +120:00 3 BPM 40 200 1425 950 +135:00 4 BPM 68 268 1800 1350 I hereby cede fo.~~orrect to the best of my knowledge Signed Title Petroleum En.qineer Date 2/26/03 · ~ -.~..,~ ~. RESOURCES (ALASKA) CORP. Januaw 16,2002 Ms. Camille Oechsli Taylor Commissioner Alaska Oil and Gas Conservation Commission 333 W. 7th Ave #100 Anchorage, Alaska, 99501-3539 RE: 10-403 - Fracture Stimulation Pioneer Unit 1702-15DA WDW APl' 50-0009-20015 Section 15 Township 17 North Range 2 West Matanuska Susitna Borough, Alaska Dear Ms. Taylor, Evergreen Resources Alaska Corporation submits the following 10-403 to hydraulically fracture stimulate the subject well. We hope to begin this work later during the week of January 27, 2003. Thank you for your time and consideration. We appreciate the help you and your staff Sincerely, Evergreen ResouJil:es (Alaska) Corp Alaska Projects Manager Attachments A~as'ka 0i~ & ,Gas Co~ts. SCANNED FEB 0 & 003 Office: 1075 Check Street, Suite 202 Wasilla, AK 99654 Mail: P.O. Box 871845 Wasilla, AK 99687 Te1:907-357-8130 Fax:907-357-8340 www. EvergreenGas.com STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: ~ susPend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: Time extension: Stimulate: xxx Change approved pro,Item: Pul~'~in~l: Variance: ~ Perforate'~ X Other;. 2. Name of Operator 5. TyPe of well: 6. Datum elevation (DF or KB) Evergreen Resources Alaska Corp Development: __ 276 ft KB (11 ff AGL) 3. Address Exploratory: 7. Unit or Property name Mailing: P.O. Box 871845, Wesilla, AK 99687 Slratigraphic: Pioneer Unit Office: 1075 Check Street, Suite 202, Wasilla, AK 99654 Service: '~"-V/ ,, , 4. Location of well at surface 8. Well number 527' FEL & 1354 FSL of Sec 15 Township 17 North Range 2 West, Seward Meridian 1702-15DA WDW At top of productive interval 9. Permit num,...l~r 527' FEL & 1354 FSL of Sec 15 Township 17 North Range 2 West, Seward Meridian 199-O64, Iniection Order 20 At effective depth 10. APl number 527' FEL & 1354 FSL of Sec 15 Township 17 North Range 2 West, Seward Meridian 50- ~3-20015 At total depth 11'. Fie'l~t/l~ool' ' ......... 52T FEL & 1,354 FSL ,of Sec 15 Township 17 North Range 2 West, Seward Meridian Tyonek "12. 'Present well condition summary Total depth: measured 4237 feet Plugs (measured) true vertical 4237 feet Effective depth: measured 4137 feet Junk (measured) true vertical 4137 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 35 13-318 to surface 35 35 Surface 675 9-5/8" to surface 675 675 Intermediate 4237 7 Stgl: 525 sx G, Stg2:215 sx 4237 4237 Production Liner Perforation depth: measured 4060-80, 3964-84, 3700-50 ft KB Tubing (size, grade, and measured depth) 2-718" J-$5/L-80, 4083 ft KB ,' 0 ' "~ Packers and SSSV (type and measured depth) None !,'"'~',["~:1 '?, "<i'11 ..... , ,, ,,~ ,'~, ,, . ' ~,~.~z.~i ' , "1'~. A~tachements .............. Des~riptio'n Summa'w of proposal: xx Detailed oPerations p~SI~'~ii ~.{~ C'lo. SOP~iil~etCh~.,'~ 14. Estimal_e~l'_ date for commencing operation 15. Status of well classification as: 1~/2o.a2"_~ i,,,,,,,, , ,,,,,, ,, ,,, ,,, ,,,,,, ,,,,,,, ,,, Name of approve, DateapproYedX 20D3 ,,, 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ,, ,, ,,,~,,,, . FOR COMMISSION,, USE ONLY Conditions of approval: Notify Commission so roprese, n~tative may witness Approval No.' ........... Plug integd~....__. . ~BOP Test X Location clearanc~......~ ~._~,~ IVlechanicallntegrityTest..~l(~ -,~ubsequentform, roquired10- ~0'7 '1~'~,~7 l~{~'p~ LO ORIGINAL SIGNED BY APProved by order of the Commissioner , , M L. Bill Commissioner Date i ~'~ Form 10-403 Rev 06/15/88 RBDHS BFL JAN 3 0 2.003 / SUBMIT IN TRIPLICATE Note to Well 1702-15DA WDW File 01/28/03 Evergreen Resource~s submitted sundry #303-023 to fracture stimulate Well 1702-15DA in three intervals below 3300' measured depth (MD). Seven major sandstones exist within the interval from 3284' (MD) and the total depth at 4237' (MD). TDS content was calculated from wireline log data of the well using the EPA endorsed method published in EPA publication "Survey of Methods to Determine Total Dissolved Solids Concentration"(KEDA Project No. 30-956). The attached table is the result of the analysis. Four sandstones contain calculated formation water TDS between 3000 parts per million (ppm) and 10,000ppm. Three sandstones contain calculated formation water TDS greater than 10,000ppm. SGANNIED FEB 0 6 2003 =V=RGI; ==I I RESOURCES (ALASKA) CORP. A Sub,';.c)a~,. oJ E~,'ecr~t, en Rer. our¢~. I~ Program Summary Pioneer Unit 1702-15DA WDW APl' 50-0009-20015 Section 15 Township 17 North Range 2 West Matanuska Susitna Borough, Alaska The subject well was drilled and permitted as a water injection well in 1999 and was issued an Aquifer Exemption No 5. In late 1999, Ocean Energy perforated 100 feet of Tertiary Tyonek zones and attempted to break down the perforations with KCI water. Injection pressures remained above 2,900 psi. In July 2002, Evergreen attempted with plug & packer to breakdown the same perforations with 7-1/2% HCI with similar/' unsuccessful results. Since Evergreen must have a functioning injection well in order to complete and then production test wells drilled last November, we propose fracture stimulating the subject well. In this procedure, intervals shown in the table below are proposed to be frac'd. Proposed Perforations & Fracture Treatment Interval Formation Shotslft Frac Description 3940-4000 Tyonek 4 50,000 lbs 20/40 Borate X-link w Nitrogen 3390-3430 Tyonek 4 50,000 lbs 20/40 Borate X-link w Nitrogen 3485-3520 Tyonek 4 50,000 lbs 20/40 Borate X-link w Nitrogen Intervals were chosen based,open hole logs, air drilled mud logs and our experience with Pilot Number 2 (Cook #1, Lowell #2, Bering #3, Baranof #4) which are on the same side of the Pittman Anticline and have similar log responses. Following this procedure, the injectivity of the well will be tested and if results look encouraging, the well will ~ mechanical integrity tests, et cetera to place this well in operation. Evergreen will utilize its own international frac fleet, single-double work over rig and water trucks currently residing in Wasilla. All frac's will occur down 2-7/8" 6.7 ppf, K-55, '/ 8 rd, EUE tubing. As specified in 20 AAC 25.280 (b)(4), fresh water will be used to control the well. This wellbore has been entered on four separate occasions and on all occasions, fresh water (8.35 lb/gal) fluid was sufficient to control the well. As specified in 20 AAC 25.280 (b)(5), the pressure gradient is normal. Thus bottom hole pressure on the bottom most interval is (4,000 ft x 0.435 psi/fi) or 1,700 psig. We plan on using 3,000 psi BOPE. / Regulation Exceptions 20 AAC 25.285: Evergreen requests that our manual BOPE, as illustrated on the next page be acceptable for this operation. 20 AAC 25.287: Evergreen requests that our Full bore lubricator on top of our BOPE is acceptable. This system is shown two pages hence. Office: 1075 Check Street, Suite 202 Wasilla, AK 99654 Mail: P.O. Box 871845 Wasilla, AK 99687 Teh907-357-8130 Fax:907-357-8340 www. EvergreenGas.com , CANNE[ i FEB 0 2003 =V=RGR==Iq RESOURCES (ALASKA) CORP. A S~s~a~, ot Evet~,ee~ ~our~s. BOP Detail Blow Out Prevention Equipment for Fracturincl and Well Clean-out Operations A schematic of Evergreen's BOPE is shown in the adjacent figure and detailed in the table below. Here we propose using 3,000 psi, 7-1/16 inch BOPE manually operated system. The BOP is attached to the 2- 7/8"x7" tubing head which is our spool in this operation. Evergreen uses a similar set-up in its operations in the Raton Basin where we frac over 1,200 stages per year using two full- time frac fleets. E~ Strip Head To Pump Wellh~d BOPE for Frac and Well Clean-out work Size Psi Manufacture No Item Manufacturer (in) Rating Year 1 Valve FMC 7-1/16 3,000 2000 2 Valve FMC 7-1/16 3,000 2000 3 Valve FMC 7-1/16 3,000 2000 4 Valve FMC 7-1/16 3,000 2000 5 Wellhead/Spool Cameron 7" csg 3,000 1996 est 6 BOP: Blind Ram Townsend ManuaIOperated 7-1/16 3,000 2001 7 BOP: Pipe Ram Townsend Manual Operated 7-1/16 3,000 2001 8 Stripping Head, High Tech Tools 7-1/16 3,000 2001 The blow out preventer is a Townsend (Odessa, TX) double gate with blind rams on the bottom and pipe rams on the top. This BOP is manually operated using two wheels. Above the BOP is a High Tech Tools (Aztec, NM) stripping head which functions as an annular preventer. The body is rated to 3z~000 ~'psi and the insert rubber, ma,,,gufactured by Triple M (Odessa, TX), designed for 2-7/8" ~bing, is pressure rated to 1,000 psi. Four manually activated FMC block valves are attached to the spool - two for the kill like and the remaining two to the choke line. The kill line is attached to an Evergreen Well Service frac truck or cement truck. Three inch 15M psi treating iron and/or 3 inch 3M psi hose will be used to connect the pump to the spool. A 15M psi valve and check valve also exists at the pump truck. The choke line connects the wellhead to a 500 bbl frac tank. Two 3,000 psi block valves at the spool will be connected to two or three inch 3M pipe running to the 500 bbl frac tank. In line with the choke line .are two 3M psi block valves located at least 20 feet from the wellhead. A conventional choke manifold is not specified in this procedure due to the shallow depths, lack of hydrocarbons, and due to our prior experience with this well bore. , SCANNED FEB 0 4 2003 Office: 1075 Check Street, Suite 202 Wasilla, AK 99654 Mail: P.O. Box 871845 Wasilla, AK 99687 Te1:907-357~8130 Fax:907-357-8340 www. EvergreenGas.com =V=I; GR==Iq RESOURCES (ALASKA) CORP. BOP Detail (Continued) Blow Out Prevention Equipment for Wireline Operations Wire line operations in this procedure consist of (1) running a cement bond log at the beginning of the job, (2) setting three RBP's and (3) perforating 135 feet of casing at a perforation density of 4 shots per foot. In all of these operations, a full bore lubricator in conjunction with our BOP set-,Pl5 will be used as our method of well control. Shown in the adjacent figure is a schematic of our proposed set-up. The table below is a detail listing of the equipment. The full bore lubricator is 20 feet in length and is fabricated out of 5-1/2", 17 lb/ft, K-55 casing. It has a pressure rating of 3,000 psig working (6,000 psi test). An oil saver seals the wire line as it passes through the lubricator is at top. Located at the bottom of the full bore lubricator is a hammer union to allow quick access to guns, setting tools and logging tools during the job. [ Blind Rams [ To Pump Tank Well control during Wire line oPerations Size Psi Manufacture No Item Manufacturer (in) Rating Year 1 Valve FMC 7-1/16 3,000 2001 2 Valve FMC 7-1/16 3,000 2001 3 Valve FMC 7-1/16 3,000 2001 4 Valve FMC 7-1/16 3,000 2001 5 Spool High Tech Tools 7-1/16 3,000 2001 6 BOP: Blind Ram TOwnsend ManuaIOperated 7-1/16 3,000 2001 7 BOP: Pipe Ram Townsend ManuaIOperated 7-1/16 3,000 2001 8 Full bore lubricator Patterson Wireline 5-1/2 3,000 1999(?) SCANNED F E B 0 A 2003 Office: 1075 Check Street, Suite 202 Wasilla, AK 99654 Mail: P.O. Box 871845 Wasilla, AK 99687 Teh907-357-8130 Fax:907-357-8340 www. EvergreenGas.com =V=EGI; ==N RESOURCES (ALASKA) CORP, Fracture Stimulation Procedure Pioneer Unit 1702-15DA WDW APl: 50-0009-20015 Section 15 Township 17 North Range 2 West Matanuska Susitna Borough, Alaska Elevations: GL: 265 ft KB: 276ft (11 ftAGL) Objective: Stimulate Tyonek formation using three-stage hydraulic fracture treatment to prepare well as a water injection well. History: The subject well was drilled in August 1999 as a water disposal well by Ocean Energy using 9-5/8" surface casing and 7", 23 ppf, J-55 casing. The first set of perforations from 3,700 to 3,750 (5 spf, 43 gr charges), were shot and broken down with 20 bbls of /~' 2% KCL. Baker SC1 permanent pac~ker set at 3,645 ff KB on 2-7/8" tubing. Perfs did not breakdown (3800 psi @ 1 bpm)."Additional perforations were added through tubing (Predator strips, 4 spf, 12 gr charges, 4,060-4,0880, 3,988-3,998, 3,964-3,984) and the entire interval was again pumped into with 20 bbls of 2% KCI. Perfs accepted fluid easier, but are still not broken down. Perfs were swabbed with little fluid recovery. In July 2002, BJ Services broke the existing perforations down for Evergreen. This procedure was unsuccessful- injection pressures too high. Currently 130 joints of 2- 7/8 tubing (4,083 ft KB) run with 2.313 XN). Now, in January 2003, Evergreen Well Service will fracture stimulate more promising intervals up hole. Evergreen purchased the subject unit and this well inA'pril 2001. If this well is not successful, then an alternate injection well ~.s...'planngd.: ........ Preparation: 1. AOGCC: Contact AOGCC (907-279-1433), Winton Aubert, 48 hours prior to operations. 2. Tanks: Two Rain for Rent 500 bbl tanks for frac and injectivity test and two additional tanks for flow-back. Three light plants are required. 3. Water: Fill both 500 bbl frac tanks with fresh water. Water sourced from City of Wasilla at 17 cents per barrel. An equivalent 4% KCI solution will be added to all water pumped/injected into well bore. Evergreen water truck in Wasilla. 4. Pumping Services: Evergreen Well Service International Frac Fleet will perform /' job. Engineer in charge is Tom Hemler with Shine Gagliardi assisting. All water will be 4% KCI water or substitute. 5. Haul Tubing: Haul 20 jts of tubing from yard and ensure that a full compliment of pups exist at location as well - pups should be on EVG Rig No. 5. 6. Hot Oiler: Used to heat frac water and to heat flow-back water provided by Pollard Wire line, Kenai 907-283-7006. 7. Steam Generator: 14 Hp Steam Generator provided by Pollard Wireline. This unit has 5 wands. SCANNED FEB 0 4: Office: 1075 Check Street, Suite 202 Wasilla, AK 99654 Hail: P.O. Box 871845 Wasilla, AK 99687 Te1:907-357-8130 Fax:907-357-8340 www. EvergreenGas.com Personnel: / Engineer in Charge: Tom Hemler 719-680-1378 2na in Engineer: Shane Gagliardi 719-859-5072 Tool Pusher: Michael Polly 719-342-5600 EWS Manager: Eric Vaughan 303-881-3557 Accommodations: Evergreen will utilize local businesses to garner support for this project. The hotel accommodations are as follows: Evergreen Well Service: Big Lake Motel 907-892-7976 Completion Rig Crew: Big Lake Motel 907-892-7976 Patterson Wireline: Houston Lodge 907-892-6808 Tom Hemler & Mike Polly Best Western 907-373-1776 Spil~ Prevention: Alaska Department of Environmental conservation has strict regulations regarding spills. All equipment will have plastic liners underneath them. Liners will also be run around wellhead. A transfer pump from the cellar to the Directions to Water Disposa~ Well: (From Wasilla): West on Parks Highway 5.8 miles to Vine Road · South on Vine Road 1.5 miles West 100 yards to location (80 ft by 40 ft green metal bldg) Casing and Tubing Data Strengths taken to 75% for Tubing and 80% of Casing I Size I Weight! ID [ Drift I Collapse ] Burst I Yield I Capacity I Capaci{~-'l ~ (in) [ ( . (i_q) .} (.psi) ]_ [psi) ] (klbs) I Bbls/ff [ Ft/bbl-[ / i Tubin 27/~;; 65 2441 23~'- --~760 5~450 544 0005794 1726 RESOURCES (ALASKA) CORP. A S~1~,, c~t Ev~r~,e'~ R~u~,'c~ 1~ Annulus I(above)[ I [ - [ - I - [ - 10.031330[ 31.91 Procedure 1. MIRU Evergreen Rig No. 5 and Evergreen Well Service (two 10,000 psi triplex pump trucks, blender, sand bins, two 500 bbl frac tanks w/heated water). Hot Oil Truck, Steam Generators (Pollard Wireline) and three 500,000 Btu Heater. s (Antigun) on location to thaw frozen lines and equipment. 0~~ NU & Test 3000,1~'manual BOP, Stripping Head and spool. RU flow-back lines to tanks. POOH with 130 joints of 2-7/8" tubing. RD Evergreen Rig. MIRU Patterson Wireline. NU Fullbore lubricator. Run Cement Bond Log. Have Tom Hemler and Shane Gagliardi analyze log before proceeding. This information will determine packer setting depth and if the bottom zone can be isolated for fracture stimulation'(~,e~ps 5-9). 5. Set Retrievable plug at t/,~t~ KB. Perforate 3,940 to 4,000 ft KB with 23 gr, 0.48, premium sha~arges on 4 guns at 4 shots/foot. RD Patterson Wireline. d¢o$o, 6. RU Evergreen Rig No. 5. 7. RIH with Baker Lockset Packer on 2-7/8" tubing to +/- 2,000 ft or depth determined by engineering. Place a 8 ft, 4 ft and 2 ft pup on top of tubing. Leave 4 ft of tubing sticking above BOP for tubing shrinkage during job. Close pipe rams. RD Evergreen Rig 5. 8. RU Evergreen Well Service. Fracture Stimulate interval down tubing with 20- 25 lb cross linked gel and 50,000 lbs of 20/40 proppant. Maximum Surface treating pressure 3,000 psi. RD Evergreen Well Service. 9. RU Evergreen Rig. Unseat packer. POOH w/tubing and packer. RD Evergreen Rig. 10. RU Patterson Wireline. Under full-bore lubricator, set RBP at +/- 3,600 ft KB. Perforate 3,485 to 3,520 ft KB with 23 gr, 0.48", premium shape charges on 4" guns at 4 shots/foot. RD Patterson. 11. RU Evergreen Rig. RIH with Baker Lockset Packer on 2-7/8" tubing. Set at +/- 2,000 ft KB or at a depth determined by engineering. Have 8 ft, 6 ft and 2ft pup joints at surface. Leave 4 ft of tubing sticking above BOP for tubing shrinkage during job. Close pipe rams. RD Evergreen Rig 5. 12. Fracture Stimulate 2® zone with 20-25 lb borate cross linked gel and 50, 000 lbs of 20/40 proppant. Maximum Surface treating pressure 3,000 psi. 13. Flow back to tank. RD Evergreen Well Service. 14. RU Evergreen Rig. Release Packer, POOH w/tubing and packer. RD Evergreen Rig. 15. RU Patterson Wireline. Under fullbore lubricator, set RBP at +/-3,470 ft KB. Perforate 3390 to 3430 ft KB with 23 gr, 0.48", premium shape charges on 4" guns at 4 shots/foot. RDMO Patterson. 16. RU Evergreen Rig 5. RIH with Baker Lockset Packer on 2-7/8" tubing. Set packer at +/- 2000 ft KB or at a depth determined by engineering. Have 8 ft, 6 ft and 2ft pup joints at surface. Leave 4 ft of tubing sticking above BOP for tubing shrinkage during job. Close pipe rams. RD Evergreen Rig 5. . . Office: :~075 Check Street, Suite 202 Wasilla, AK 99654 Hail: P.O. Box 871845 Wasilla, AK 99687 Teh907-357-8130 Fax:907-357-8340 www. EvergreenGas.com ,SCANNED FEB 0 z~. 200~ =V=I GR==N RESOURCES (ALASKA) CORP. 17. Fracture Stimulate 3rd zone wJth 20-25 lb borate cross linked gel and 50,000 lbs of 20/40 proppant. MaxJmum Surface treating pressure 3,000 psi. RD Evergreen Well Service. 18. SWIFN. 19. POOH with Baker Lockset Packer on 2-7/8" tubing. 20. RIH with retrieving head on 2-7/8" tubing. CJrculate sand off of RBP. / Retrieve RBPs and clean hole to PBTD at 4,137 ft KB. 21. Clean-out hole. 22. 23. Set Lockset packer at 3,000 ft KB. Test Injectivity of well using frac pumps and 4% KCI fluid. If well accepts fluid, then perform tasks to place well on injection (MIT, et/'''' cetera). If well does not accept fluid, then consult with Evergreen Alaska Engineering. SCANNED FEB 0 z~ 2003 Office: 1075 Check Street, Suite 202 Wasilla, AK 99654 Mail: P.O. Box 871845 Wasilla, AK 99687 Teh907-357-8130 Fax:907-357-8340 www. EvergreenGas,com Ever,qreen Resources Alaska Corp Pioneer Llnit 1702 15DA WDW Well Section 15 Township 17 North Range 2 West APl: 50-0009-20015 ~-,~ew Pe~s showr'~ ~ ~ed {ef~ s~de of WBD) 13-3/8" Conductor Casing 1 3.375", 68 ppf, 0-35 ft KB 9-5/8" Surface Casing 9-5/8", 36 ppf, 0 - 675 f1 KB Cement 400 sx + Top Job Circ to Surface DV Tool @ 1,822 KB New Per~s (3 390..3,430) -- 48 ft 4 JSPF, 23 gr Charges X-Link Frac with 50 Mlbs 20/40 7" Production Casing 7", 23 ppf, 0 - 4237 ft KB Cement in 2 Stage (DV = 1,822 ft KB) Stage 1: 515 sx Class G (Circ t00 bbls to pit) Stage 2: 215 Sx Class G (Circ 51 bbls to pit) Hew Pe~s (3 485 3 520) - 35 It 4 JSPF. 23 gr Charges X~Link Frac with 50 Mlbs 20/40 Existing Perforations (3,700-3,750) - 50 ft 5 JSPF. 43 gr Charges Bkdn#1 (3,700-50): 20 bbts 2% KCI, End Rate 1 BPM @ 3800 psi 75 bbls of 2.5% HCI in July 2002 Existing Perforations (3,964-3,984 and 39,88 - 3,998) - 30 ft 4 JSPF, 43 9r Charges Bkdn#2 (All Perfs): 20 bbls 2% KCI. End Rate 1.8 BPM @ 3100 psi 45 bbls 7.5 % HCI Existing Perforations (4,060-4,080) - 20 ft 4 JSPF. 12 gr Charges Bkdn#2 (All): 20 bbls 2% KG, End Rate 1.8 BPM @ 3100 psi 30 bbls 7.5% Hd 01/28/03 Salinity Calculation From Wireline Logs Temp Rmf 66.00 Total Depth 4235.00 Temp at TD 92.00 Temp @ Surface 35.00 Temp Gradient 1.35 Matrix Density 2.65 Matrix TT 53.00 Compaction Factor 1.50 a 1.00 m 2.00 Well 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW Depth/top Rt Density 3284 14.9 2.46 3285 16.3 2.43 3286 18.2 2.42 3287 20.6 2.47 3288 22.6 2.56 3289 23.2 2.62 3290 22.7 2.58 3291 20.7 2.49 3292 18.3 2.43 3293 17.2 2.43 3294 17.2 2.42 3295 17.1 2.41 3296 17.1 2.42 3297 18.2 2.42 3298 19.7 2.41 3299 20.0 2.49 3300 20.1 2.57 3301 20.4 2.49 3302 19.8 2.41 3303 19.3 2.40 3304 19.2 2.43 3305 18.6 2.45 3306 17.3 2.46 3307 16.0 2.45 3308 15.0 2.45 3432 11.8 2.42 3433 11.9 2.42 Porosity- Density porosity Neutron Porosity-cross Salinity 0.12 0.29 0.21 8389 0.14 0.30 0.22 6907 0.14 0.29 0.21 6218 0.11 0.27 0.19 7080 0.05 0.23 0.14 11676 0.02 0.19 0.11 22173 0.04 0.19 0.11 18740 0.10 0.23 0.16 9740 0.13 0.26 0.20 7519 0.13 0.26 0.20 8043 0.14 0.27 0.20 7316 0.15 0.29 0.22 6505 0.14 0.29 0.21 6657 0.14 0.28 0.21 6538 0.14 0.27 0.21 6168 0.10 0.23 0.16 9871 0.05 0.21 0.13 15560 0.10 0.25 0.17 8753 0.14 0.28 0.21 5775 0.15 0.26 0.21 6392 0.13 0.25 0.19 7584 0.12 0.26 0.19 7582 0.12 0.26 0.19 8697 0.12 0.26 0.19 9225 0.12 0.27 0.20 9201 Average 9132 0.14 0.28 0.21 9834 0.14 0.27 0.21 10392 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 702-15DA WDW 702-15DA WDW 702-15DA WDW 702-15DA WDW 702-15DA WDW 702-15DA WDW 702-15DA WDW 702-15DA WDW 702-15DA WDW 702-15DA WDW 702-15DA WDW 702-15DA WDW 702-15DA WDW 702-15DA WDW 702-15DA WDW 702-15DA WDW 702-15DA WDW 702-15DA WDW 702-15DA WDW 702-15DA WDW 702-15DA WDW 702-15DA WDW 702-15DA WDW 702-15DA WDW 702-15DA WDW 702-15DA WDW 702-15DA WDW 702-15DA WDW 702-15DA WDW 702-15DA WDW 702-15DA WDW 702-15DA WDW 702-15DA WDW 702-15DA WDW 702-15DA WDW 3434 3435 3436 3437 3438 3439 3440 3441 3442 3443 3444 3445 3446 3447 3448 3449 3450 3451 3452 3453 3454 3455 3456 3457 3458 3459 3460 3461 3462 3463 3464 3465 3466 3467 3468 3469 3470 3471 3472 3473 3474 3475 3476 3477 3478 3479 348O 3481 11.7 11.4 11.5 12.0 12.9 14.3 16.4 18.2 18.7 18.0 16.7 14.8 13.5 13.1 13.3 14.1 15.0 15.5 15.9 16.3 16.7 17.1 17.3 17.7 18.1 17.7 17.3 17.2 16.5 15.6 15.5 16.4 17.4 17.5 17.4 16.7 15.8 15.6 16.1 16.4 16.6 17.2 17.4 17.2 17.4 17.6 17.2 17.2 2.41 2.39 2.39 2.44 2.46 2.50 2.52 2.51 2.54 2.58 2.57 2.48 2.44 2.44 2.43 2.43 2.43 2.43 2.46 2.46 2.45 2.46 2.45 2.49 2.51 2.46 2.47 2.53 2.50 2.47 2.46 2.45 2.45 2.48 2.52 2.48 2.44 2.45 2.46 2.46 2.49 2.50 2.47 2.49 2.52 2.48 2.47 2.50 0.14 0.16 0.16 0.13 0,11 0.09 0.08 0.08 0.07 0.04 0.05 0.10 0.13 0.13 0.14 0.13 0.14 0.13 0.11 0.12 0.12 0.12 0.12 0.10 0.09 0.11 0.11 0.07 0,09 0.11 0.12 0.12 0.12 0.10 0.08 0.11 0.13 0.12 0.12 0.11 0.10 0.09 0.11 0.10 0.08 0.10 0.11 0.09 0.27 0.28 0.28 0.28 0.26 0.24 0.25 0.24 0.21 0.19 0.19 0.22 0.25 0.28 0.28 0.28 0.28 0.28 0.28 0.27 0.29 0.30 0.29 0.31 0.30 0.27 0.24 0.21 0.22 0.23 0.24 0.23 0.23 0.21 0.18 0.20 0.23 0.25 0.25 0.25 0.26 0,26 0,26 0.23 0.22 0.23 0.25 0.22 ,SCANNED FEB 0.20 0.22 0.22 0.20 0.19 0.17 0.16 0.16 0.14 0.11 0.12 0.16 0.19 0.20 0.21 0.21 0.21 0.21 0.20 0.19 0.21 0.21 0.21 0.20 0.19 0.19 0,17 0.14 0.15 0.17 0,18 0,17 0.18 0.16 0.13 0.15 0.18 0.19 0.19 0.18 0.18 0.17 0.18 0.16 0.15 0.17 0.18 0.15 0 4 2003 10745 9394 9362 10422 11657 13542 119O0 11306 14579 24000 23069 14122 11079 9637 9072 8596 7790 7777 8187 8464 7203 7014 6867 6871 7727 7853 10200 15958 13885 11338 10868 10540 9331 12403 17928 13941 10530 9295 9448 9661 9790 10109 8725 11337 13825 10810 9265 13152 702-15DA WDW 702-15DA WDW 702-15DA WDW 702-15DA WDW 702-15DA WDW 702-15DA WDW 702-15DA WDW 702-15DA WDW 702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 702-15DA WDW 702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 3482 3483 3484 3485 3486 3487 3488 3489 349O 3700 3701 3702 3703 3704 3705 3706 3707 3708 3709 3710 3711 3712 3713 3714 3715 3716 3717 3718 3719 3720 3721 3722 3723 3724 3725 3726 3727 3728 3729 3730 3731 3732 3733 3734 3735 3736 17.1 16.6 16.3 16.1 15.9 15.2 13.9 12.7 11.6 13.1 13.6 14.1 14.2 14.0 13.7 13.3 13.1 12.9 12.9 13.5 14.8 16.3 17.9 18.4 17.6 16.7 16.2 17.1 19.5 22.4 23.4 22.3 21.3 19.9 18.8 19.0 20.5 22.4 24.4 25.6 25.6 24.1 21.6 20.0 19.0 18.3 2.47 2.46 2.45 2.45 2.44 2.44 2.45 2.45 2.48 2.59 2.63 2.60 2.54 2.51 2.50 2.54 2.56 2.54 2.53 2.53 2.53 2.54 2.58 2.62 2.63 2.64 2.59 2.52 2.51 2.51 2.52 2.51 2.48 2.42 2.41 2.43 2.46 2.46 2.50 2.54 2.52 2.52 2.50 2.49 2.47 2.45 0.11 0.12 0.12 0.12 0.13 0.13 0.12 0.12 0.10 0.22 0.24 0.25 0.26 0.26 0.24 0.25 0.25 0.28 Average 0.04 0.01 0.03 0.07 0.09 0.09 0.07 0.06 0.07 0.07 0.08 0.08 O.07 0.04 0.02 0.01 0.00 0.04 0.08 0.09 0.09 0.08 0.09 0.10 0.14 0.14 0.14 0.12 0.11 0.09 0.07 0.08 0.08 0.09 0.10 0.11 0.12 0.25 0.20 0.21 0.25 0.25 0.25 0.27 0.28 0.29 0.31 0.29 0.28 0.26 0.22 0.18 0.17 0.18 0.22 0.26 0.25 0.23 0.21 0.21 0.21 0.25 0.29 0.27 0.27 0.27 0.25 0.22 0.22 0.22 0.24 0.25 0.25 0.27 0.16 0.18 0.19 0.19 0.19 0.18 0.18 0.18 0.19 0.14 0.11 0.12 0.16 0.17 0.17 0.17 0.17 0.18 0.19 0.18 0.18 0.16 0.13 0.10 0.09 0.09 0.13 0.17 0.17 0.16 0.14 0.15 0.16 0.19 0.22 0.21 0.19 0.19 0.17 0.15 0.15 0.15 0.17 0.17 0.18 0.20 11326 9590 9175 8810 8779 10186 11207 12247 12072 10919 20019 36949 26678 14757 12648 13001 13734 13756 12890 10882 11037 10813 11495 16369 29647 37431 38935 19271 10538 8805 9004 10250 10336 9706 6571 5563 6103 6496 5789 6983 9125 8785 8999 8146 8378 7978 6929 $C;,ANNED FEB 0 4:2003 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 3737 18.7 2.46 0.11 0.29 0.20 3738 20.3 2.47 0.11 0.27 0.19 3739 23.1 2.48 0.10 0.26 0.18 3740 27.8 2.52 0.08 0.25 0.16 3741 30.3 2.55 0.06 0.23 0.15 3742 28.7 2.55 0.06 0.22 0.14 3743 27.4 2.59 0.04 0.21 0.12 3744 24.8 2.51 0.08 0.22 0.15 3745 22.4 2.47 0.11 0.26 0.18 3746 21.7 2.50 0.09 0.26 0.18 3747 21.5 2.51 0.09 0.26 0.17 3748 20.5 2.49 0.10 0.24 0.17 3749 18.9 2.48 0.10 0.25 0.17 3750 18.3 2.49 0.10 0.26 0.18 3751 19.7 2.51 0.08 0.27 0.18 3752 21.8 2.52 0.08 0.26 0.17 3753 22.1 2.49 0.10 0.26 0.18 3754 23.0 2.52 0.08 0.21 0.15 Average 0.16 3820 3821 3822 3823 3824 3825 3826 3827 3828 3829 3830 3831 3832 3833 3834 3835 3836 3837 3838 3839 3840 3841 3842 3843 3844 3845 3846 3847 12.2 12.8 13.3 13.6 14.0 15.0 16.9 18.8 20.4 21.3 20.6 19.5 19.2 19.8 21.2 22.9 23.5 23.3 23.0 21.4 19.5 18.0 16.3 14.9 13.9 13.6 14.4 16.7 6472 6708 6180 6564 7691 8535 12418 8789 6536 7094 7589 8497 8560 8159 8099 7585 7065 9884 1767.66 SCANNED FEB 0 & 2003 2.49 0.10 0.27 0.18 12193 2.50 0.09 0.25 0.17 13766 2.51 0.08 0.23 0.16 15072 2.50 0.09 0.24 0.17 13006 2.48 0.10 0.26 0.18 11107 2.48 O. 10 0.26 O. 18 10168 2.49 0.10 0.24 0.17 10218 2.51 0.09 0.24 0.16 9975 2.51 0.09 0.27 0.18 7291 2.49 O. 10 0.28 O. 19 6343 2.49 O. 10 0.26 O. 18 7449 2.48 0.10 0.26 0.18 7678 2.48 0.11 0.25 0.18 8001 2.48 O. 10 0.23 O. 17 8839 2,48 O. 10 0.23 O. 17 8070 2.50 0.09 0.25 0.17 7345 2.53 0.07 0.24 O. 15 8778 2.57 0.05 0.21 O. 13 12597 2.59 0.04 0.21 0.12 14311 2.56 0.06 0.21 0.14 12657 2.53 0.07 0.23 0.15 11323 2.54 0.07 0.22 0.15 13216 2.54 O. 07 O. 22 O. 14 15467 2.54 0.07 0.23 0.15 15081 2.53 0.07 0.24 0.15 15518 2.51 0.08 0.22 0.15 15714 2.51 0.09 0.22 0.15 15252 2.50 0.09 0.22 O. 16 11969 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 3848 20.1 2.47 0.11 0.26 0.18 7207 3849 24.1 2.48 0.10 0.27 0.19 5753 3850 28.9 2.52 0.08 0.25 0.16 6186 3851 31.3 2.54 0.07 0.24 0.15 6403 3852 31.2 2.53 0.08 0.24 0.16 6265 3853 30.9 2.53 0.07 0.24 0.16 6245 3854 31.1 2.54 0.07 0.26 0.16 5957 3855 31.5 2.56 0.06 0.27 0.16 5751 3856 31.6 2.56 0.06 0.25 0.15 6586 Average 10129 3968 22.7 2.48 0.11 0.26 0.18 6298 3969 23.2 2.47 0.11 0.27 0.19 5627 3970 22.5 2.47 0.11 0.25 0.18 6333 3971 20.7 2.49 0.10 0.24 0.17 7997 3972 18.3 2.48 0.11 0.25 0.18 8123 3973 16.4 2.45 0.12 0.26 0.19 8059 3974 15.5 2.46 0.11 0.26 0.19 8899 3975 15.0 2.49 0.10 0.26 0.18 10247 3976 14.7 2.50 0.09 0.26 0.18 10460 3977 14.8 2.50 0.09 0.26 0.18 10339 3978 15.5 2.50 0.09 0.25 0.17 10354 3979 16.7 2.49 0.10 0.24 0.17 10001 3980 16.8 2.48 0.10 0.26 0.18 8679 3981 15.9 2.52 0.08 0.24 0.16 12131 3982 14.7 2.59 0.04 0.21 0.12 22774 Average 9755 4060 26.9 2.57 0.05 0.18 0.12 13639 4061 25.9 2.63 0.02 0.17 0.09 22117 4062 24.5 2.61 0.02 0.19 0.10 18743 4063 22.3 2.50 0.09 0.23 0.16 7943 4064 20.5 2.42 0.14 0.26 0.20 5746 4065 19.8 2.40 0.15 0.26 0.21 5448 4066 19.4 2.40 0.15 0.27 0.21 5249 4067 19.2 2.40 0.15 0.29 0.22 4909 4068 18.8 2.41 0.15 0.28 0.22 5233 4069 18.5 2.41 0.14 0.27 0.21 5938 4070 18.3 2.42 0.14 0.28 0.21 5841 4071 17.9 2.42 0.14 0.28 0.21 5875 4072 17.7 2.42 0.14 0.27 0.21 6241 4073 17.3 2.44 0.13 0.27 0.20 6926 4074 16.8 2.44 0.13 0.26 0.20 7232 4075 16.5 2.44 0.13 0.26 0.19 7565 4076 16.2 2.44 0.13 0.27 0.20 7579 4077 15.9 2.45 0.12 0.28 0.20 7288 4078 15.9 2.46 0.12 0.28 0.20 7677 4079 15.9 2.45 0.12 0.28 0.20 7347 FEB 0 2003 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 1702-15DA WDW 4080 16.1 2.43 0.13 0.27 0.20 7195 4081 16.3 2.43 0.14 0.27 0.20 6865 4082 16.6 2.44 0.13 0.27 0.20 7207 4083 17.1 2.41 0.14 0.29 0.21 5885 4084 18.4 2.41 0.15 0.28 0.21 5557 4085 21.2 2.40 0.15 0.26 0.20 5177 Average 7785 4160 22.1 2.59 0.04 0.30 0.17 7397 4161 25.3 2.54 0.06 0.30 0.18 5425 4162 28.6 2.53 0.08 0.29 0.18 4615 4163 30.5 2.50 0.09 0.30 0.19 3875 4164 30.9 2.47 0.11 0.30 0.20 3476 4165 31.2 2.47 0.11 0.30 0.20 3474 4166 32.0 2.49 0.09 0.28 0.19 3916 4167 32.5 2.49 0.10 0.29 0.19 3701 4168 31.1 2.50 0.09 0.28 0.19 4198 4169 29.3 2.54 0.07 0.27 0.17 5384 4170 28.1 2.55 0.06 0.28 0.17 5685 4171 26.8 2.52 0.08 0.28 0.18 5361 4172 26.7 2.53 0.07 0.27 0.17 5667 4173 27.9 2.52 0.08 0.27 0.17 5468 4174 26.9 2.54 0.07 0.26 0.17 6144 4175 22.2 2.60 0.03 0.25 0.14 10827 Average 5288 · ..SCANNED FEB 0 4 2003 _V_RGR=_=I RESOURCES (ALASKA) CORP. A Subsidiary of Evergreen Resources,/nc. November 15, 2002 Winton Aubert Commissioner Alaska Oil and Gas Conservation Commission (AOGCC) 333 West 7th Ave. #100 Anchorage, AK 99501-3539 RE: Report of Sundry Well Operations (Form 10-404) Pioneer Unit- Well 1702 15DA WDW Dear Mr. Aubert: Please find attached the Report of Sundry Well Operations for the well work operations performed on well 1702 15DA WDW. The attached report details the stimulation activities that occurred. Approximately 450 barrels of Class II wellbore fluids were generated as a result of the stimulation activities and disposed of in the well. However, ongoing disposal of Class II fluids has not commenced. Please contact me should you have any questions. My e-mail address is JohnT@EvergreenGas.com, and my cell phone, which is the best way to reach me, is 907-841-0000. Sincerely, EVERGREEN RESOURCES (ALASKA) CORP. Alaska Projects Manager Bcc: Lynx Enterprises, Inc. (file) P.O. Box 871845 · Wasilla, AK 99687 · TEL 907,357.8130 · FAX 907,357,8340 RECEIVED NOV 1 2002 Alaska Oil & Gas O0ns. Commission Anchorage STATE OF ALASKA (' ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operation performed: Operation shutdown Stimulate X Plugging Perforate Pull Tubing After casing Repair well _ ~ ~,~I~ 6. Datum elevation (DF or KB): DF 12' AGL 2. Name of Operator: Evergreen Resources (Alaska) Corporation ,.~'~i P..,[~ 7. Unit or Property Name: Pioneer Unit 3. Address: P.O. Box 871845, Wasilla, AK. 99687 8. Well number: 1702 15DA WDW 4. Location of well at surface: 9. Permit Number/Approval Number: Sec. 15, T17N, R2W 199-064 Disposal Injection Order 20 At top of productive interval: same 10. APl Number: At effective depth: same 50-00009-20015 At total depth: same 11. Field and Pool: Pioneer 12. Present well condition summary: Total depth: measured 4237 feet Plugs (measured) None true vertical 4237 feet Effective depth: measured 4137 feet Junk (measured) None true vertical 4137 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 35' 13-3/8" To surface 35' 35' Surface 675' 9-5/8" To surface 675' 675' Intermediate Production 4237' 7" Stg: 515 sx G, 4237' 4237' Stg 2:215 sx Liner Perforation depth measured 3700'-3750', 3964'-3984', 4060'-4080' True vertical 3700'-3750',RECEIVED 3964'-3984', 4060'-4080' Tubing (size, grade, and measured depth) 2-7/8", J-55 at 3645' NOV 1 9 2002 Packers and SSSV (type and measured depth) Baker SC-1 packer at 3645' ~a$1(~ 0ii & Gas Col]s, 60m1111~$$~011 Anch0ra~e 13. Stimulation or cement squeeze summary: See attached data provided by BJ Services Intervals treated: Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Oil Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to Well Operation 0 0 451.5 Max: 2,970 Max: 2,970 Ave: 1,957 Ave: 1,957 Subsequent to Operation 0 0 0 0 0 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys Run Xrl~'T"~~~ Daily Report of Well Operations Oil [] Gas [] Suspended'l-1 Service 17. I hereby certi.,fy that th,~ foregoing is true and correct to the best of my knowledge. '-" ~J Signed Title Alaska Projects Manager Date 11/5/2002 Date 27-AUC-.-.-.-.-.-.-.-~ District Kenai Lease PIONEER UNIT 17132 15~ , Field . pIONEER Treatment Report-Supplement Well Name Location StageNo, Custlxnel' pIONEER. UNIT 170.2 Evemreen Resources Inc I Well APl. - APl 500092001501XX) TIME .AMP, M 17:13 t7:24 17:25 17:26 17:31 17:34 17:37, 17:39 17:41 17:42 ' 17:44 17:46 17:47 17:49 . 17:51 Treating Preesum. F~i STP' ' Annulus .. 3200 3.300 3,375 3365 33.55 Surface Slurry eeLS. Pumm~ ,, . Stage Tote Sluny Rate BPM Corem 13:55 from 1st upright lank, pacieer ~ so m to inject into3 18:37 17:40 240O 158 Minimum Treating Fluid Maximum Flush Average Ava'age 3.25 4.5 I.~hUt In O.n-~ to wail; haE_in ir~.iee~ of 2nd 2nd .uDdght amev..~ sa~ch tO 1st frac tank_ Stat ~ ~ 1at fra: tank (3m tank) 15 Min. "Final In Flush Dens. lb./gaL Transmi~_.ion ouerh-~: drop. AL pump. out o~ _hair. 3rd tank out of fluid, stop pumping, unseat packer, mn in to isolate Customer Rep. Dave Walters 245O BJ Rep. Robert Moore Job Number 1001115817 RaG. ID No. DiStrlbutfon Min. Ret, oft Prfnted on: September{;, 20024:5,4 PM JrS001 Treatment Report-Supplement D~le 27..At~2 ~ Ker~i F.Re~q~ 1001115817. C,u~ E~mmen R~,~ume~ I~ :~ ~R UNff'l~l~ W~~. P~ UNff 1~ 1~ , F~ , ~R ~ ~. ~ ~~. ~ ~ ~~ ~ wd~ .... ~'~~ , .. T~ T~ ~~i Su~ S~ S~ ~ , .,~ .~..~ ~ ~ ...... 17:~ 1~ 8 ~~ d ~ ~ mn~, sh~ ~, ~ ~ to ~ s~ ....... 1~:~ .2~0 2~ 2 ~P~ ~. , ..... 19;~ 2~ ..... 1 'P~ ~ ...... ~9:~ 2414 ~, .5 ~~ ~. . ,, 19:42 ~ , ,~ .5~P~~ ...... 19:47 2~ ~ .3;~~ ~, ~9:~ ~ ~ .5~~ ..... 19:~ ~ , , .5 ~~ ~. 19:~ 24~ , ~ /. 1 ~~~. .. 19:51 2~ r ~ / 2 I~ ~ , ,, 19:~ 27~ i ~ ~ 3 I~ ~. .,~:s~ ~ ...... '" ' /~ ~ .~ ~ ~ ~ ~ ~ .~..=~ ,, ~:o7 ~ , s ~ ~ ~ ~. - ,, , ~:12 ~7o 10 ~ ~ ~ , , , ~:~ 21~ .', ' 2D mb sh~ ~ ~um ....... ~:~ 21~ 25 ~ sh~ ~ ~_ o7:~ .,. I~~_ ~f~mm.~~'~.~. ' ~s:m ~ ,,, , ,, ~.,--~.~..~.'~~,,' L ' .. 15:28 2~ [Shm ~ ~um ,, . 15:~_ ~ ; 5 ,, 2 ~h. T~'~. .... J.~ ~ .... s~ ~. ~ ...... c~ ~. o~ w~ ~~ T~m F~ " fSDP 2~ ~ R~. R~ ~ ~ F~h 5 M~. J~ N~ lm111~17 .. &~ A~ 10 M~. R~. ID No. F~ In ~ .... ~_ , ........ iF~h ~. ~.lga.' .... , ,, ,, ,, ,,, , ,, , ,,., Repor~ Primed on: september 5, 2002 4:54 PM JrSO01 ~KA OIL AND GAS CONSERYA~ION C0~O~I$SION TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-14,.'.'~ FAX (907) 276-7542 ADMINISTRATIVE APPROVAL NO. DIO 20.001 Mr. John Tanigawa Alaska Projects Manager Evergreen Resources (Alaska) Corp. PO Box 871845 Wasilla AK 99587 Re: Request for Disposal of Cement Rinsate in Pioneer Unit Well #1702-15DA Dear Mr. Tanigawa: By letter dated September 19, 2002, Evergreen Resources (Alaska) Corporation requested authorization to dispose of cement rinsate into the pre-existing Pioneer Unit Well #1702-15DA, permitted as an Underground Injection Control Program Class II disposal well..The Pioneer Unit. is a pilot coalbed methane development located within the Matanuska Valley, near the citY.of " Wasilla, Alaska. The project involves as many as 12 wells drilled to test the viability of coalbed methane production in Alaska. On October 30, 2002, Evergreen provided laboratory analysis of a representative sample of cement rinsate from Baranoff #4 well that is currently being drilled'at the Pioneer Coalbed Methane Project location. Data provided by Evergreen demonstrates that the cement rinsate proposed for disposal does not exhibit any hazardous characteristics as defined in 40 CFR 261. The letter forwarding the analytical results of the cement rinsate indicates that Evergreen will, upon approval by the AOGCC, "place the rinsate into the cuttings pit for later disposal" into Well #1702-15DA. The cement rinsate noted in Evergreen's request is generated in primary field operations intrinsic to the drilling of exploration and production wells at the Pioneer Unit. Cement rinsate is consistent in composition with materials already authorized for injection under Disposal Injection Order No..20 and pose no risk of fluid movement into a USDW. Underground injection into this Class II disposal well represents the envirOnmentally preferable option for managing the cement rinsate generated in conjunction with the drilling of Evergreen's coalbed methane development wells when compared to surface discharge, the only other viable option. The AOGCC has determined that the cement rinsate, as represented in Evergreen's request for administrative approval, is suitable for disposal in Pioneer Unit Well #1702-15DA as proposed. No injection into this well may occur until Evergreen has performed a mechanical integrity test as required in 20 AAC 25.252(d). Approval applies only to this specific request and is not DIO 20.001 November 1, 2002 Page 2 of 2 intended to provide for a blanket authorization to inject these or similar non-hazardous fluids down other Class II disposal wells. DONE at Anchorage, Alaska and dated November 1, 2002. Cammy~echsli T~Y~r Chair Daniel T. Seamount Commissioner Michael L. Bill, PE Commissioner BY ORDER 0 ', Pioneer 1702-15DA WDW Sundry Notice - no change Subject: Pioneer 1702-15DA WDW Sundry Notice - no change Date: Thu, 22 Aug 2002 13:52:41 -0800 From: John Tanigawa <JohnT@EvergreenGas.com> To: "Winton Aubert (E-mail)" <Winton_Aubert~admin.state.ak.us> Winton, Thank you for taking the time to talk with David, Gene and myself today. I appreciate your help and your time on this matter. We have reviewed AAC 25.285 (c) (10) (A) regarding the choke manifold. We believe that the sundary notice is fine as written and does not need to be changed. This is because the max pressure encountered will be less than 5K. Again, there is an HCR valve on the spool for the 3" choke line. Thank you again John T. $CANNE SEP 1 2002 :R'ES;OUFICE$ (AL.:AS.KA) ~OR P;' August 20, 2002 Mr. Winton Aubert Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 7th Avenue Anchorage, AK 99501 RE' Evergreen Resources Alaska Carp Pioneer Unit 1702 15DA WDW Section 15 Township 17 North Range 2 West Pioneer Unit Matanuska Susitna Borough Dear Mr. Winton, A Sundry for the subject well was submitted on Friday, August 16,' 2002 for the purposes of breaking down existing perforations shot in 1999. AS a result of today's conversation, this document revises the well control aspects of this well operation and requests waivers from AAC 25.285, SECONDARY WELL CONTROL FOR TUBING WORKOVER OPERATIONS: BLOWOUT PREVENTION EQUIPMENT REQUIREMENTS paragraph (h). This revised well control approach very closely conforms to the current AOGCC regulations. It utilizes existing rental equipment from DSR and Weatherford in Alaska. We have been assured that this same equipment has been repeatedly used and been approved by the AOGCC in similar set-ups. Description of BOPE: The subject well has a 3,000 psi 7-1/16ths inch wellhead, to which we will install the following (from bottom up): 7-1/16" inch (5M) Spool · 7-1/16" inch (5M) Schafer double gate BOP with 1 Blind (bottom) and~ Ram (top) · 7-1/16" inch (5M) /~Schaf~r Annular Preventer ~_~.~_ The BOPE system will 1se hydraulically operated using an accumulator sourced from DSK in Kenai. This accumulator conforms with 25 AAC 25.285 (c 6 and c 8 A and B), remote activation of the BOPs. The spool and BOP are sourced by Weatherford, Kenai. A diagram of this BOP stack is shown, including the valving for the 2", 5,000 psi kill line and the 3", 5,000 psi choke line. Evergreen Resources Alaska BOPE Setup for 1702-15DA WDW Cl~oke LIneq .... 1, 7-1/16" 5M Spool w/2" 5M & 3" 5M OTL 2, 3" 5M Companion Flange w/3" LP 113reacJs 3. 3" 5M Remote Control Hydraulic Valve 4, 3" 5M Manual Gate Valve 5, 2" 5M Manual Gate Valve 6. 2" 5M Manual Gate Valve 7, 2" Companion Flange w/2' LP Threads The kill tine begins with two manually operated 5,000 psi gate CANNEC, SEP 1 200 P.O. Box 871845 Wasilla, AK 99687 Tel: 907-357-8130 Fax: 907-357-8340 RESOURCES (ALASKA) CORP. valves and a companion flange with 2" NPT male connector. From this 2" NPT, a BJ Services Cementer will be hooked-up ready to kill the well. The choke tine begins with a manually operated 3" 5,000 psi gate valve followed by a 3" 5,000 psi hydraulically activated control valve and 3" 5,000 psi companion flange. The choke valving will then be connected to a 8 to 10 foot 3", 5,000 psi line to the choke manifold. Choke Manifold Description The 2", 5,000 psi choke manifold will be located approximately 10 feet away from the 3 inch companion flange on the BOP stack. This manifold is being temporarily released from the Marathon rig doing work on the Kenai. The manifold has all of the essential elements of a choke manifold as described in AAC 25.285 - adjustable chokes, valving and a bypass line. A photo of the Weatherford manifold is shown below. Description of Kill Truck A BJ Services cement truck will be on standby when not pumping the acid stimulation. This truck will be used to kill the well in case of blow out. The pump has sufficient horsepower to overcome any foreseeable rates and pressures required for a kill operation for the subject well. , · P.O. Box 871845 Wasilla, AK 99687 Tel: 907~357-8130 Fax: 907-357-8340 Waiver Requests Evergreen Resources Alaska Corp requests two waivers from AAC 25.285: 1. AAC 25.285 e6 - states that no hammer unions can exist on the choke lines. The Weatherford Choke Manifold has a 2" 15,000 psi hammer union that connects the choke line to the choke manifold. Since this connection is rated to 15,000 psi, and is used routinely to stimulate/cement wells throughout the world, we request a waver from this specific regulation. Furthermore, this set-up is currently being used by other operators in the Cook Inlet. 2. AAC 25.285 f2 - states that the BOP must be retested if it were used. As a part of daylight operations, the BOP stack will be used to shut the well in at night. In this case, tubing will be left in the hole. We request a waiver such that we test the BOP once during the job, and not every day. AAC 25.285 is attached. The specific regulations are highlighted in red, including AAC 25.285 (h), which grants the commission authority to grant the waiver request. We have rescheduled this work to begin early next week. For Evergreen's future completions, we will submit a very comprehensive waiver request. Current regulations are not amenable to shallow gas development. We look forward to work with you on this endeavor before we begin drilling. Thank you again. Sincerely, Evergreen Resources Alaska Corp John J. Tanigawa Alaska Projects Manager $CANNEB SEF 1% 2002 P.O. Box 871845 Wasilla, AK 99687 Tel: 907-357-8130 Fax: 907-357-8340 20 AAC 25.285 SECONDARY WELL CONTROL FOR TUBING WORKOVER OPERATIONS: BLOWOUT PREVENTION EQUIPMENT REQUIREMENTS. (a) This section applies to workover operations performed with the tree removed. These operations are also subject to the requirements of 20 AAC 25.527. (b) The rated working pressure of the BOPE and other well control equipment must exceed the maximum potential surface pressure to which it may be subjected. If an approved Application for Sundry Approvals (Form 10-403) is required under 20 AAC 25.280, the commission will specify in that approved application the working pressure that the equipment must be rated to meet or exceed. However, the rated working pressure of the annular type preventer need not exceed 5,000 psi. (c) Well control equipment must include (1) at least one positive seal manual or hydraulic valve or BOPE blind ram and one set of BOPE pipe rams flanged to the wellhead; (2) in rotary drilling rig operations, (A) for an operation requiring a BOP stack less that APl 5K, at least three preventers, including (i) one equipped with pipe rams that fit the size of drill pipe, tubing, or casing being used, except that pipe rams need not be sized to bottom-hole assemblies (BHAs) and drill collars; (ii) one with blind rams, except that a subsea BOPE assembly must have blind/shear rams in place of blind rams; and (iii) one annular type; and (B) for an operation requiring a BOP stack equal to or greater than APl 5K, at least four preventers, including (i)'two equipped with pipe rams that fit the size of the drill pipe, tubing, or casing being used, except that pipe rams need not be sized to BHAs and drill collars; (ii) one with blind rams, except that a subSea BOPE assembly must have blind/shear rams in place of blind rams; and (iii) one annular type; (3) in coiled tubing unit operations, (A) for an operation requiring a BOP stack equal to or less than APl 5K, (i) BOPE rams providing for pipe, slip, cutting, and blinding operations on the coiled tubing in service; (ii) a high pressure pack-off, stripper, or annular type preventer; (iii) if pressure deployment of tools is planned, a riser or lubricator sized to the BHA and providing for pressure integrity from the BOPE rams to the high pressure pack-off, stripper, or annular type preventer; and (iv) at least one preventer equipped with pipe rams that fit the size of the tubing, liner, or casing being used, except that pipe rams need not be sized to BHAs and drill collars; and (B) for an operation requiring a BOP stack greater than APl 5K, (i) BOPE rams providing for pipe, slip, cutting, and blinding operations on the coiled tubing in service; (ii) two high pressure pack-offs, strippers, or annular type preventers; (iii) if pressure deployment of tools is planned, a riser or lubricator sized to the BHA and providing for pressure integrity from the BOPE rams to the high pressure pack-off, stripper, or annular type preventer; and P.O. Box 871845 Wasilla, AK 99687 SCANNED SEP 200 _ Tel: 907~$57-8150 Fax: 907-357-8340 -- . (A~S.~.~i.~,o.,,:. .R'E~OURCE$: (iv) at least two preventers equipped with pipe rams that fit the size of the tubing, liner, or casing being used, except that pipe rams need not be sized to BHAs and drill collars; (4) if a tapered string is used, either an additional set of rams for each size of pipe being run or a variable ram, except if small diameter tubulars are used to perform a clean-out operation through a production packer or to clean out a liner where the casing has been top set; (5) locking devices on the ram-type preventers; (6) in rotary drilling rig operations, one complete set of operable remote BOPE controls on or near the driller's station, in addition to controls on the accumulator system; (7) in coiled tubing operations, one complete set of operable remote BOPE controls on or near the operator's station and, if these controls are not in close proximity to the drilling platform floor, a second annular type preventer closing control located on the drilling platform floor; (8) a hydraulic actuating system with (A) sufficient accumulator capacity to supply 150 percent of the volume necessary to close all BOPs, except blind rams, while maintaining a minimum pressure of 200 psi above the required precharge pressure when all BOPs, except blind rams, are closed and all power sources are shut off; and (B) an accumulator pump system consisting of two or more pumps with independent primary and secondary power sources and an accumulator backup system having sufficient capacity to close all BOPs and to hold them closed; (9) a kill line and a choke line each connected to a flanged or hubbed outlet on a drilling spool or on the BOP body with two full-opening valves on each outlet, conforming to the following specifications: (A) the outlets must be at least two inches in nominal diameter, except that for rotary drilling rig operations, if the required BOP is rated equal to or greater than APl 5K, the nominal diameter of the choke outlets must be at least three inches; (B) each valve must be sized at least equal to the required size of the outlet to which it is attached; (C) the outer valve on the choke side must be a remotely controlled hydraulic valve; (D) the inner valve on both the choke and kill sides may not normally be used for opening or closing on flowing fluid; and (10) a choke manifold equipped with (A) two or more adjustable chokes, one of which must be hydraulic and remotely controlled from near the driller's station if the operation requires a BOP stack equal to or greater than APl 5K; (B) a line at least two inches in nominal diameter downstream of each choke; (C) immediately upstream of each choke, at least one full-opening valve for an operation requiring a BOP stack less than APl 5K, or at least two full- opening valves for an operation requiring a BOP stack equal to or greater than APl 5K; and (D) a bypass line, at least two inches in nominal diameter, with at least one full-opening valve for an operation requiring a BOP stack less than APl 5K, or at least two full-opening valves for an operation requiring a BOP stack equal to or greater than APl 5K. SCANNED! SEP ]. 2,.005 P.O. Box 871845 Wasilla, AK 99687 Tel: 907-357-8130 Fax: 907-357-8340 (d) The rated working pressure of valves, pipes, rotary hoses, and other fittings, including all sections of the choke manifold that are subject to full wellhead pressure, must exceed the maximum potential surface pressure to which they may be subjected and may not be less than the required working pressure specified for the BOPE in an approved Application for Sundry Approvals, if any, under 20 AAC 25.280, except that the rated working pressure of lines downstream of the choke need not exceed 50 percent of the required working pressure of the BOPE. (e) Kill and choke lines must (1) be constructed of rigid steel pipe, fire-resistant rotary hose, or other conduit that has been approved by the commission as capable of withstanding the temperature and pressure of an ignited uncontrolled release; (2) be as straight as practical; (3) if constructed of rigid steel pipe, use targeted turns where the bend radius is less than 20 times the inside diameter of the pipe; (4) be secured to prevent excessive whip or vibration; (5) be sized to prevent excessive erosion or fluid friction; and (6) be assembled without hammer unions or internally clamped swivel joints, unless the commission determines that those joints do not compromise the maintenance of well control. (f) The BOPE must be tested as follows: (1) when installed, repaired, or changed, and at least once a week thereafter, BOPE, including emergency valves and choke manifolds, must be function pressure-tested, using a non-compressible fluid, to the required working pressure specified in an approved Application for Sundry Approvals under 20 AAC 25.280 or, if that application is not required, to the maximum potential surface pressure to which the BOPE may be subjected, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; (2) if BOP sealing ram type equipment has been used, it must be function pressure-tested before the next wellbore entry, using a non-compressible fluid, to the required working pressure specified in an approved Application for Sundry Approvals under 20 AAC 25.280 or, if that application is not required, to the maximum potential surface pressure to which that equipment may be subjected, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; (3) non-sealing equipment must be function-tested weekly, after a repair or change, and after an action that disconnects the hydraulic system lines from the BOPE, except that if the workstring is continuously in the well, function- testing must be performed as soon as possible after the workstring is pulled out of the well and the BHA clears the BOP; (4) test results must be recorded as part of the daily record required by 20 AAC 25.070(1); (5) at least 24 hours notice of each function pressure test must be provided so that a representative of the commission Can witness the test. (g) In a rotary drilling rig operation, the operator shall have on location a copy of the approved Application for Sundry Approvals, if that application is SCANNEC,' SEP :~ '~, ?OD? P.O. Box 871845 Wasilla, AK 99687 "Eel: 907-357-8130 Fax: 907-357-8340 required under 20 AAC 25.280, and shall post on the drilling rig floor any geologic hazard information obtained while drilling the well and a copy of the operator's standing orders specifying well control procedures. In a coiled tubing operation, the operator shall post in the operator's cab a copy of the approved Application for Sundry Approvals, if that application is required under 20 AAC 25.280, any geologic hazard information obtained while drilling the well, and a copy of the operator's standing orders specifying well control procedures. If an additional or separate substructure is used in a coiled tubing operation, the operator shall post a second set of standing orders on the drilling platform floor. (h) Upon request of the operator, the commission will, in its discretion, approve a variance from the requirements of this section if the variance provides at least an equally effective means of ensuring well control. H/story - Eft. 4/2/86, Register 97; am 11/7/99, Register 152 Authority - AS 31.05.030 ,SCANNED, SEP }. 2, 201')2 P.O. Box 871845 Wasilla, AK 99687 Tel: 907-357-8130 Fax: 907-357-8340 i' i" . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION cOMMISSION D ~ 6:~'//~ ~ APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [ ] Abandon [ ] Suspend [ ] Plugging [ ] Time Extension [ ] Perforate [ ]Alter Casing [ ] Repair Well [ ]Pull Tubing [ ]Variance ./ [ ]Other [ ] Change Approved Program [ ] Operation Shutdown [ ] Re- Enter Suspended Well [X] Stimulate 2. Name of Operator 5. Type ofwell: 6. Datum Elevation (DF or KB) Evergreen Resources (Alaska) Corporation [ ] Development DF 12' AGL [ ] Exploratory 3. Address [ ] Stratigraphic 7. Unit or Property Name P.O. Box 871845, Wasilla, Alaska 99687 [X] Service ~ Pioneer Unit 4. Location of well at surface 8. Well Number / 527' FEL, 1354' FSL, Sec. 15, T17N, R2W 1702-15DA WDW At top of productive interval 9. Permit Number Same 199-064 At effective depth 10. APl Number Same '50-00009-20015 At total depth 11. Field and Pool Same Pioneer 12. Present well condition summary Total depth: measured 4237 feet Plugs (measured) None true vertical 4237 feet Effective depth: measured 4137 feet Junk (measured) None true vertical 4137 feet Casing Length Size Cemented MD TVD Structural Conductor 35' 13-3/8" Cemented to surface 35' 35' Surface 675' 9-5/8" Cemented to surface 675' 675' Intermediate Production 4237' 7" Stg 1' 515 sx G, Stg 2:215 sx 4237' 4237' Liner Perforation depth: measured 3700'- 3750', 3964'- 3984', 4060'- 4080' ii?! i.: (~ ...... ii..... ~ !? ~'' True vertical 3700' - 3750', 3964' - 3984', 4060' - 4080' Tubing (size, grade and measured depth) 2-7/8", J-55 at 3645' Packers and SSSV (type and measured depth) Baker SC-1 packer at 3645' '"~ © !'' '''~ '':~' ..... i'3. Attachments [ ] Description of Sumary Proposal [X] Detailed Operations Program [X] BOP Sketch 14. Estimated date for commencing operation 15. Status of well classification as: ' 8/21/02 z' .... i6. If propoSal was verbally approved []Oil [ ]Gas [ ]Suspended Name of approver. Date Approved ,Service: Water Disposal Well ' Contact Engineer Na.,c~umber: John Tanigawa g07-841-0000 Prepared By Name/Number: John Tanigawa ~07-841-0000 17. I hereby certify ~~ue andSigned c°rrect t° the best °f mY kn°wledge ,,,~f,~ Title Alaska Projects Manager Date f p~pr7 Commission Use Only ~°nditions o Notify Commission so representative ma~ ~/itness IApproval No, Plug integrity~ BOP Test ~ Location Clearance Mechanical Integrity Test ~ Subsequent form required 10- c~/-o ~ q~-<J ~. PE r~t ~' ~ ~e.~[ Commissioner Date '~Z-710-Z.._., ~ Approv~ ~y order of~el~om~is ~or; ~(z_ ,,:~ ~[,.. .. Form 10-403 Rev. 06/15/88 RESOURCES (ALASKA) CORP. ,4 Subsic~a,3, of Eve~qreen Resources, Inc. Acid Breakdown & Matrix Stimulation Procedure Pioneer Unit 1702-15DA WDW APl: 50-0009-20015 Section 15 Township 17 North Range 2 West Matanuska Susitna Borough, Alaska Elevations: GL: 265 ft KB: 276 ft (11 ft AGL) Objective: Breakdown existing perforations using 7-1/2% hydrochloric acid and place the well on injection. If this treatment is unsuccessful, then the well will be hydraulically fracture treated. History: The subject well was drilled in August 1999 as a water disposal well by Ocean Energy using 9-5/8" surface casing and 7", 23 ppf, J-55 casing.. The first set of perforations from 3,700 to 3,750 (5 spf, 43 gr charges), were shot and broken down with 20 bbls of 2% KCL. Baker SC1 permanent packer set at 3,645 ft KB on 2-7/8" tubing. Perfs did not breakdown (3800 psi @ 1 bpm)/'^dditional perforations were added through tubing (Predator strips, 4 spf, 12 gr charges, 4,060-4,0880, 3,988-3,998, 3,964-3,984) and the entire interval was again pumped into with 20 bbls of 2% KCI. Perfs accepted fluid easier, but are still not broken down. ~ Perfs were swabbed with little fluid recovery. No further work has been done on this well. Evergreen purchased the subject unit and this well in April 2001. Water disposal facilities were modified and are now nearing completion. This procedure will attempt to remove damage from the near well bore created by the polymer mud system used. Preparation: 1. Install dead men in work over doghouse. Remove wellhouse. 2. Tanks: Finalize two (for flow back & 6% KCI water) 500 bbl frac tanks and two/. 116 bbl poly tanks for HCI from Rain for Rent (907-398-6919). Tanks to be delivered on Tuesday, August 20, 2002. 3. Water: Fill one 500 bbl frac tank with fresh water. Water sourced from City of Wasilla at 17 cents per barrel. Evergreen water truck in Wasilla. / 4. Pumping Services: BJ Services, Jay Garner, (907-349-6518). Acid ordered. 330 gal totes to be delivered directly to location. Will mix 7% HCI (with inhibitor, Iron sequesterant and surfactant), and 6% KCI. BJ to source, mix and pump HCI and KCI. Contacts: Well Site Supervisor Alaska Projects Manager Dave Walters John Tanigawa 505-320-0384 ' 907-841-0000 SCANNED SEP 1 g 2002 RESOURCES (ALASKA) CORP. A Subsid~a~' of Evergreen Resources, Inc. Procedure (Three Days) Wednesday, 21 August 2002 1. 2. / MIRU Evergreen Well Service Rig #5' Install and Test 3000 psi, Townsend Type 81 BO~P 7-1/16", 300,0 p, si B, OP Blind Ram and 1 Pipe Ram, Man_.~tion. 3. Unseat Baker SC Packer at 3,645 ft KB on 2-7/8", 6.7 ppf, J-55 tubing. 4. POOH & LD SC Packer. Have Packer redressed at Baker Oil Tools, Anchorage. 5. RIH w/Baker Plug and Packer in 7" 23 ppf casing to +/-3,600 ft KB. 6. SDWFN Thursday, 22 August 2002 7. MIRU BJ Services 8. Pick up extra joints of 2-7/8" casing and set plug at +/- 4100 ft KB, below bottom set of perforations. PBTD = 4137 ft KB. 9. Circulate tubing volume of 6% KCI water followed by 10 bbls of 7-1/2 % HCI at 2 bpm to pickle tubing. Displace acid with full annular volume to pit. 10,. Set packer at +/-4,010 ft KB. 11 .Acidize 1st Zone (4,060'-4,080' KB) with 30 bbls of 7-1/2% acid. See acid pumping procedure below. 12. Retrieve plug & reset to 4020 ft KB. 13. Move up and set packer at 3925 ft KB. 14.Acidize 2® zone (3964-3985 & 3988-3998) with 45 bbls of 7-1/2" HCI. See acid pumping procedure below. 15. Reset Plug to +/-3825 ft KB 16. Set Packer at +/-3560 ft 17.Acidize 3rd Zone with 75 bbls 7-1/2% HCI. If perfs sufficiently broke down, then RDMO BJ. See acid pumping procedure below. If pressures are still high, then have BJ wait for 1 day to test injectivity after the acid has spent on formation. 18. Retrieve Plug & POOH 19. LD Plug 20. RIH with Packer on tubing 21. Set Packer at 3650 ft 22. Tubing Swab Well 23. SWIFN. Friday 24. 25. 26. 27. 28. 23 August 2002 Using BJ Pump, test Injectivity using 6% KCI fluid & dispose of remaining fluid in tanks. RDMO BJ. POOH & LD Packer RIH with SC-1 Packer. Pressure Test Tubing to 3,000 psi with blow-out plug. Connect well to Injection facilities. SCANNED,' SEP 1 ~ 2002 Acid Pumping Procedure Place 700 psi pressure on annulus, Monitor this pressure during job. Maximum pressure is 3;500 psi.' Begin pumping at 1 bpm until breakdown. In middle/end of breakdown, perform step rate test to characterize type of friction (perforations versus pipe). Vary Rates from %, 1, 2 & 4 BPM: Directions to Water Disposal Well: (From Wasilla) West on Parks Highway 5.8 miles to Vine Road South on Vine Road 1.5 miles West 100 yards to location Casing and Tubing Data Strengths taken to 75% for Tubing and 80% of Casing I ~;P~_ [ 2:7/8" 6.5% 2.441 2,347 ~ 5,760 ~ 5,450 ~ 54.4~~ 172.6 ~ Casin9 ~ 7 ..~ 23 ~-~;;B6 ] 6.~5i 2,~'~-~ 3,500 )~%-~ 0,039380 [' Annuus (above) ~' 7 [ ~ ~ % ' %F '] ~ ~0031330 BOP Detail New Townsend 7-1/16" x 3,000 psi BOP 1 Blind Ram (bottom)' 1 Pipe Ram (top) Lt~~.~& cl ~'~ Manua~rated Attach to 3,000 wellhead. Note: This BOP arrangement will include a 7-1/16", 1,000 psi WP annular preventer on top of the rams. Weight Dimension Data Overall height, less'studs Overall Length Overall Width, less hand sheet Opening through preventer Working Pressure Test Pressure 2,200 lbs 20-1/2" 63" 22" 7-1/16" 3,000~ 6,000~ SCANNED SEP 1 B 2002 Evergreen Resources A~aska Corp Pioneer Unit ~702 ~5DA WDW We~l Section ~5 Township ~7 North Range 2 West APk 50-0009-200~ 5 DV Tool @ 1,822 KB Tubing 6.7 ppf, J-55 Baker SC 1 Pkr Surface to 3,645 Packer @ 3,645 ft KB 13-3/8" Conductor Casing 13.375", 68 ppf, 0-35 ft KB 9-5/8" Surface Casing 9-5/8", 36 ppf, 0 - 675 ft KB Cement 400 sx + Top Job Circ to Surface 7" Production Casing 7", 23 ppf, 0 - 4237 ft KB Cement in 2 Stage (DV = 1,822 ft KB) Stage 1: 515 sx Class G (Circ 100 bbls to pit) Stage 2: 215 Sx Class G (Circ 51 bbls to pit) ACID JOB ¢3 75 bbls 7-1/2" HCI Existing Perforations (3,700-3,750) - 50 ft 5 JSPF, 43 gr Charges Bkdn#1 (3,700-50): 20 bbts 2% KCI, End Rate 1 BPM @ 3800 psi AC;(1 JOe #2 45 bbs 7-i/2" -lC Existing Perforations (3,9,64~3,984 and 39,88 - 3,998) - 30 ff 4 JSPF, 43 er Charges BkdrC¢2 (All Peris): 20 bus 2% KCI, End Rate 1.8 BPM @ 3100 psi ACE} JOB ¢¢1 30 bbs % /2 i{C! Existing Perforations (4,060-4,g80) - 20 ff 4 JSPF. 12 gr Charges Bkdn#2 (All): 20 bbts 2% KCI, End Rate 1.8 BPM @ 3100 psi ALASiIA OIL AND GAS CONSERVATION CO~LMISSION 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 50-009-2001.7 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 15.DA-WDW, Permit Number 99-64, APl Number 50-009-20015 1) Sepias and paper copies of all logs run in the well. (hdil/dal/gr/cal, ldl/cn/gr/cal, sbt) Pioneer Unit well 14CC, Permit Number 99-65, API 'Number 50-009-20016 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 25.07'I (b) (4) 5) 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. 5) Sidewall core analysis and descriptions Loretta Murphy '"':'"' "t 2 May3;?2"~:" ' Production Analyst Ocean Energy, Inc. Pioneer Unit well BLT #1 RE, Permit Number 99-68, API Number 50-009-20006-90 1) Digital sbt data 2) Sbt sepia We note you have made a significant effort to comply with the reporting requirements of 20 AAC 25.071, however all of this information is long overdue and is considered very important to this developing play. If we have not been advised in writing by May 26, 2000 as to the disposition of these materials, I will recommend the Commission undertake an enforcement action as described in 20 AAC 25.535. Notwithstanding, AOGCC recognizes the importance and potential benefit of OE's coalbed methane program to the State of Alaska. We look forward to your continued success as well as a good working relationship with the Commission. Please give me a call at (907)-793-1230 if you'd like to discuss this matter. Sincerely Robert P. Crandall ..... Senior Petroleum Geologist CC~ Robert Christenson Cammy Oechsli-Taylor Dan Seamount V la. Type of work Drill: X Redrilh 't' Re-Entry: Deepen: I 2'. Name of Operator PERMIT TO DRILL Type of well Exploratory: ~ Strati[~' . nic Test: Service: ~, Developement Gas: X~. Single Zone: Ocean Energy, Resources, Inc. 3. Address 1670 Broadway, Suite 2800, Denver, CO 80202-4826 Sec. 15-T17N-R2W 4. Location of well at surface 527' FEL & 1354' FSL At top of productive interval 527' FEL & 1354' FSL At total depth 527' FEL & 1354' FSL feet 13. Distance to nearest well NA feet Maximum hole angle: 5. Datum Elevation (DF or KB) GL: 265' KB: 276' feet 6. Property Designation ADL-374117 7. Unit or property Name Pioneer Unit 8. Well number d'~15DA WDW 9. Approximate spud date Upon Approval 14. Number of acres in property 2721.06 10. Field and Pool Pioneer Unit Development Oil: Multiple Zone: 11. Type Bond (see 20 AAC 25.025) Number JZ-8072 Amount $200,000.00 15. Proposed depth (MD and TVD) 17. Anticipated pressure (~e 20 AAC 25.035 (e)(2)) Maximum sue'face 1410 psig At total depth (TVD) 4,100' feet 12. Distance to nearest property line 527' 16. To be completed for deviated wells Kickoff depth: feet 18' Casing pr°gram I I Settini Depth size Specifications Top Bottom Hole I Casing WeightI Grade I Coup,ngl Length MD I ~V= M= ! ~V~ 17-1/2" 13-318" 68~ J-55 ST&C 35' Surf. Surf. 35' 35' 1500 Quantity of cement (include stage data) 35 sx 12-114" 9-5/8" 36~ J-55 ST&C 700' Surf. Surf. 700' 700' I 8-3/4" 7" 23~ WC-50 ST&C 4100' Surf. Surf. 4100° 4100' 400 sx 1st 221 sx I I 19. To be completed for Reddll, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet true vertical feet Plugs (measured) Effective depth: measured feet true vertical feet Junk(measured) Casing Length Structural Conductor Surface Intermediate Production Liner Perforation depth: measured Size Cemented Measured depth .., 2nd 121 sx 3rd 113sx True vertical depth true vertical ,' .... ' ............ 20. Attachments: Filing fee: XX Property Plat: XX BOP Sketch: XX Diverter Sketch: NA Drilling program: Ddlling fluid program: XX Time vs. depth plot: Refraction analysis:. Seabed report: 20 AAC 25.050 requirements: 21. I herby certify that the foregoing is true and correct to the best of my knowledge: Signed: ~~.~ .~~ .~,~'~' Title: Regulatory Coordinator Commission Use Only Date: 6/28/99 Permit Number [ APl number J Approval date ~... /~.,~, I See cover letter I C~'~,,, ~" ~ I 50-4::~O ? ..-, ,2.. O cS / ~ I '~ ",~ ~ ~f'7 I for other requirements I Cond~en~ of aPproval Samples required: [ ] Yes ;r~ No Mud'log required: [ ] yes J~ No I Hydrogen sulfide mea~sel'~[~ ] Yes...~ No Directional survey required [ ] Yes J~ No I R.equiredworkingp/ssurefor~~ ~U; []3~; [ISM; [] 10M; [] 15M ,- [Other. '/~,'"// '/ //// ! , , / ~"'""-~'--////'/'""~.. ..... by order of l Approve(~y /~,'~~ L ~~~~_ .. Commissioner the Commission Fo-'~-40~Rev. 12-1-~- - 20/:~A,C 25.005 Date: 7-~..~'~1~ . . Submit in triplicate 'APE ;3 0 2002 199-064-0 PIONEER UNIT 1702 Roll #1: Start: Stop Roll #2: MD 04265 ~'VD 04265 'Completion Date: 15DA-WD 50- 009-20015-00 OCEAN ENERGY RESOURCES, INC Start Stop a<ff~99 Completed Status: WDSPL Current: T Name Interval D 9551~ I OE DIFL/ZDL/CN/DAL 2 DISKS L CXDL/CN/DIFL FIELD LGR 673-4235 L DAC/DIFL ~'' FIELD LGR 0-4236 L DIGITALS~ECTRAI~ ....... FIELD LGR 673-4191 L DIPLOG ~ FIELD LGR 673-4233 L SANDSTONE SRVY C'~FIELD LGR 0-4246 L SBT ~~' FIELD LGR 10-4133 Sent Received OH 4126/00 4/26/00 OH 2/5 4/26/00 4/26/00 OH 6 4/26/00 4/26/00 OH 6 4/26/00 4/26/00 OH 6 4/26/00 4/26/00 OH 5 4/26/00 4/26/00 CH 5 4/26/00 4/26/00 T/C/I) Wednesday, June 20, 2001 Page 1 °fi STATE OF ALASKA ALASKA OIL( ND GAS CONSERVATION 6(' VIMISSION - WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well OIL: GAS: SUSPENDED: ABANDONED: SERVICE: X 2. Name of Operator Ocean Energy Resources, Inc Classification of Service Well 7. Perr~it Number 99-64 3. Address 8. APl Number P. O. Box 549, Newcastle, WY 82701 50- 009-20015 Sec 15 T17N R2W 4. Location of well at surface 1354' FSL & 527' FEL At Top Producing Interval 1354' FSL & 527' FEL At Total Depth 1354' FSL & 527' FEL 9. Unit or Lease Name Pioneer Unit 10. Well Number 1702-15DA WDW 11. Field and Pool Pioneer Unit 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. GL 265': KB 276' I ADL 374117 12. Date Spudded 13. Date T.D. Reached I 14. Date Comp., SusB. or Aband. I 15. Water Depth, if offshore 16. No. of Completions 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD'~ 119. Directi~nai Survey -I 20. Depth where SSSV Set Thickness of Permafrost 4265' 4137' I Yes: No: X I N/A feet MD I N/A 22. Type Electric or Other Logs Run Digital Spectralog, Compensated Z-Densilog, Segmented Bond Tool, Digital Acoustilog, Basic Diplog, Sand Stone Analysis 23. 13 3/8" 9 5/8" CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP I BOTTOM 68# J55 surface 135' ~6# J55 35' 675' 23# CF-50 675' . 4255' 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) 3700~3750' 5SPF .25" hole 3964'-3984' 4SPF .22" hole 3988'-3998' 4SPF .22" hole 4060'-4080' 4SPF .22" hole HOLE SIZE 17 1/2" 12 1/4" 18 3/4" CEMENTING RECORD AMOUNT PULLED 30 sx class G None 550 sx class G !None 515 sx class G Non~ 25. TUBING RECORD SIZE 2 7/8" 26. DEPTH SET (MD) PACKER SET (MD) 4130' 3645' ACID, FRACTURE, CEMENT SQUEEZE, .ETC. DEPTH INTERVAL(MD) 3700-3750' 3964'-3984' 3988'-3998' AMOUNT & KIND OF MATERIAL USED 120 BBLs 2%KCL Wtr; 110 gal C~rr. In'hibl 41bbls 2%KCL+5%Nonionic Surfactant+ 1%EDTA for 3 seis perfs. 4060'-4080' 27. Date First Production 10/20/1999 Date of Test I Hours Tested 10/20/1999 148 hrs Flow Tubing I Casing Pressure I Press. 2650 PRODUCTION TEST IMethodofOperation(Flowing, gaslift, etc.) 'r'"'l! f!")'! !P WDW; test info is from AOGCC approved injectivity test; well is currently shut in : ' ' .... . .... ./ ,,. PRODUCTION FOR TEST PERIOD => OIL-BBL 0 CALCULATED OIL-BBL GAS-MCF 24-HOUR RATE ---> 0 0 28. CORE DATA GAS-MCF J WATER-BBL 0 J1150 J WATER-BBL J2 BPM CHOKE SIZE J GAS-OIL RATIO OIL GRAVITY-APl (corr) Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. /'-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 3O. GEOLOGIC MARKERS '?)RMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT'. DEPTH GOR, and time of each phase. ._. Glacial Deposits ISurf. Tyonek 490' Tyonek B Coal 1080' Tyonek B Sand 1380' Tyonek C Sand 1812' Tyonek C Coal 2660' Tyonek P Coal 3408' "31. LIST OF ATTACHMENTS 32. I' hereby certify~at the foregoing is true and correct to the best of my knowledge ..... .. ,-.- r-. ..... , -- f -:{' . .......... 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 comp eted. for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the productin intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be'' separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Well Summary Report Well ID: Pioneer 170215DA Ocean Energy Well Name: Pioneer Unit #1702-15DA Operator: AFE Nos: Spud Date: Section: Location: Ocean Energy, Inc. DWI901; DWI901C; DWI901D 29-Jul-99 15 Township: 17N 1354' FSL & 527' FEL Reports for 06:00 on date shown 31-Jul-99 01 -Aug-99 02-Aug-99 Field: Pioneer Unit Range: 2W Current Depth: 11 Hole Drilled: 11 Ave ROP: Present Ops: rig acculmultor not working properly, having to repair or get new closing unit. Down until can get up to snuff. Operations Summary: Weld on 13 5/8 starting head, nu 13 5/8 5M diverter assembly w/10" blooie line, build flow line & bell nipple. Change desander to discharge over drying shaker. (24 hrs) Mud Data: MW: 8.6 Viscosity: 165 Filtrate: 0 HTHP Filtrate: 0 Surveys: None Days S.S.: 0 Daily Costs: $224,540 Well Costs: $224,540 Current Depth: 16 Hole Drilled: 5 Ave ROP: Present Ops: drilling ahead in gravel Operations Summary: accumulator not working properly, no nitrogen in ball. (12 hrs) function test diverter, test accumulator system (0.5 hrs) move desander to drying shaker, insatll fill-up line at bell nipple (10.5 hrs) 11-16, 5 ft, 1/2 hr, spud 2300 hfs 8-1-99, (0.5 hrs) change packing in mud transfer pump (0.5 hrs) Mud Data: MW: 8.6 Viscosity: 180 Filtrate: 12.8 Surveys: None Days S.S.: 1 Daily Costs: $16,524 Well Costs: 10.0 $241,064 Current Depth: 16 Hole Drilled: 202 Ave ROP: 11.9 Operations Summary: 12-48 36 ft, .83 fph. Very rough (6.5 hrs) tighten kelly hose, came loose due to rough drilling (1.5 hrs) 48-112 64 ft 18.2 fph, still rough (3.5 hrs) right angle drive bolts sheared, replace same (0.5 hrs) lube and check bolts on rig and tighten same (0.5 hfs) 112 - 188 76 ft 16.8 fph (4.5 hrs) pop-off on pump parted, pooh, replace pop-off, work on transfer pump, tih (4.5 hrs) 188- 218 30 ft 12 fph installed button bit and smoothed out (2.5 hrs) Comments: the drilling is much smoother since installed button bit. All seems to be going OK now. The rig repairs should be at a minimum now. Mud Data: MW: 8.95 Viscosity: 210 Filtrate: 12.4 HTHP Filtrate: 0 Page 1 Well Summary Report Well ID: Pioneer 170215DA Ocean Energy Well Name: Pioneer Unit #1702-15DA 03-Aug-99 04-Aug-99 Surveys: None Days S.S.: 2 Daily Costs: $0 Well Costs: $241,064 Current Depth: 675 Hole Drilled: 457 Ave ROP: 33.9 Present Ops: pooh to run surface csg, Running 9 5/8 J-55 stc 8 rd @ 0500 hrs 8-4-99 Operations Summary: tight conn, raise wis and cir hole clean (1 hrs) 218 - 307 89 ft, 25.4, button bit makes much difference, drilling smooth (3.5 hrs) 267 ft 1/2 deg (1 hrs) 307-438 131 ft, 4 hrs 32.75 fph (4 hfs) cir and clean transfer tank (1.5 hrs) 438 - 523 85 ft 42.5 fph top or tyonek 490 as per geology (2 hrs) lube rig (0.5 hrs) 489 1 deg (0.5 hrs) 523 - 675 152 ft, 38 fph 2 coals with 320 unit gas (4 hrs) cir (1 hrs) wiper trip to surface, small bobble first 60, wipe 1 time then OK. (1.5 hrs) tih w/o problems no fill (1 hrs) cir & condition to run csg. (1.5 hfs) pooh to rn csg, no problems, SURVEY 2 DEG @ 635, MAY BE A LITTLE SUSPECT AS TOTCO HAS NO FEATHERS AND INSTRUMENT WAS DROPPED. (1 hrs) Comments: drilled surface w/o hole problems, will run button bit on surface from now on instead of mill tooth. Mud Data: MW: 9.7 Viscosity: 60 Filtrate: 10 HTHP Filtrate: 0 Surveys: None Days S.S.: 3 Daily Costs: ($73,121) Hole Drilled: 0 Well Costs: $167,943 Ave ROP: Current Depth: 675 Present Ops: @ 0430 done welding on wellhead and letting well head cool down. Operations Summary: LD 8" DC (1 hfs) Run 15jts 9 5/8 36# J-55 STC, work thru for 1 1/2 at 165 ft, rot 3/4 turn and went thru ledge and cont to bttm w/o problems, 8 ft fill. Set in tension on bttm (7 hrs) cir (2.5 hrs) held prejob safety meeting for cmting. Spill control & response (0.5 hrs) cmt w/400 sx G w/2% cacl, 1/4#/sx cello flakes, 1.16, 15.8 82 bbls slurry, 10 bbls good cmt returned (1 hrs) Wait on Cmt (6 hrs) cut off csg, nd diverter (6 hrs) Comments: letting wellhead cool at rt. Install went good. Will start nu within a couple hrs. Est time for nu 6 hr, test bop 3 hrs. (need to install 4-way valve for HCR), run bond log 2 hrs. Pu bha #2, 2 hrs. Test csg for 1/2 hr., drl out & preform FIT 3 hrs. These times are best guess. Mud Data: MW: 9.7 Viscosity: 60 Filtrate: 10 HTHP Filtrate: 0 Page 2 Well Summary Report Well ID: Pioneer 1702'15DA Ocean Energy Well Name: Pioneer Unit #1702-15DA 05-Aug-99 06-Aug-99 07-Aug-99 Surveys: None Days S.S.: 4 Daily Costs: $115,963 Well Costs: $283,906 Current Depth: 675 Hole Drilled: Ave ROP: Present Ops: fabricating bell nipple at present time. Operations Summary: weld on 11" 3M SOW w/Hot Head (6 hrs) Nu 11" 3 M LWS Ram. Install choke line, HCR and manifold line, Gas buster w/flare stack. (15 hrs) wait on annular that went to shop for refit (3 hfs) Comments: moved geology unit to loc. Annular arrived at 0100 hfs on 6-Aug-99. Rig replaced mud transfer pump, put suction in suction pit for 2nd pump. Should be testing bop in about 2 hrs. 4 hrs test bop, 2 hrs run bond log, 2 hrs pu bha & tih, 1 hr for csg test. Mud Data: MW: 0 Viscosity: 0 Filtrate: 0 HTHP Filtrate: 0 Surveys: None Days S.S.: 5 Daily Costs: $20,785 Well Costs: $304,691 Current Depth: 675 Hole Drilled: Ave ROP: Present Ops: waiting on parts for bop, seals Operations Summary: wait for arrival of annular from shop (1 hrs) nu annular, finish rest of nu (11 hrs) attempt to test BOPE, no test, seals gone from ram pistons, could not get any test, will have to fly parts in from lower 48 as no arts available in AK, did cmt bond log with Baker Atlas while waiting for parts. Cmt top 220 ft but have cmt to surface around surface pipe. (12 hrs) Comments: rdid the bond log while waiting for parts for rams. Top of cmt is 220 ft but we have cmt to surface and couldn't get cmt in the well without perforataing the surface pipe. Mud Data: MW: 8.85 Viscosity: 41 Filtrate: 13.6 HTHP Filtrate: 0 Surveys: None Days S.S.: 6 Daily Costs: $20,476 Well Costs: $325,167 Current Depth: 675 Hole Drilled: Ave ROP: Present Ops: repair bop Operations Summary: wait on bop parts, tear down bop, parts got to Anchorage 2300 hrs. 8-8-99 (24 hrs) Comments: It appears that we blew the seals out of Ithe bops, There was not a regulator between the accumulator ball and the 4-ways valves. What ever pressure the rig hydraulics had is what the ram pressure was when opened and closed. Normally you keep the manifold pressure at 1500 while the Koomey is kept at 2000 or 3000. The recommended max pressure for the bop is 1500 and we had up to 2100 on the rig hydraulics. While down the toolpusher made a jet line for the mud transfer pit so can Page 3 Well Summary Report Well ID: Pioneer 170215DA Ocean Energy Well Name: Pioneer Unit #1702-15DA 08-Aug-99 09-Aug-99 now jet the transfer pit. That along with the new transfer pump should cure any problems with the transfer system. Only 1/2 of the parts arrived, putting bop back together at this time with old parts, it should be OK but they wanted to put all new parts in just to be sure. If not we will not be out anything. If all goes OK will be together in 3 hrs or so. Mud Data: MW: 8.7 Viscosity: 38 Filtrate: 14.8 HTHP Filtrate: 0 Surveys: None Days S.S.: 7 Daily Costs: $23,170 Well Costs: $348,337 Hole Drilled: Ave ROP: Current Depth: 675 Present Cps: installing rot head, installing lines from bas buster to flow line Operations Summary: repair bops (8 hrs) test choke manifold, blinds, pipe rams 2000 high 300 Iow. Annular fail. Witnesswed by Larry Wade AOGCC (5 hfs) nd annular, nu rot head and associated lines (11 hrs) Comments: the annular would hold 600 psi but no more. Need 1500 as per regulations. Rig up to the Lynn rotating head, (rig equip), make and weld up line to gas buster. CHP is flying in an annular to Anc and should arrive 8-10-99. A Grant rotating head left the North Slope morning of 8-- 8-99 and should arrive Fairbanks @ 1200 noon 8-9-99. The drive bushing and etc for it are now in Fairbanks and as soon as all arrives it will be brought to Icc. Aanticipate that to be evening of 8-9-99. MW: 8.7 Viscosity: 34 Filtrate: 14.8 HTHP Filtrate: 0 Daily Costs: $19,985 Well Costs: $368,322 Mud Data: Surveys: None Days S.S.: 8 Ave ROP: Current Depth: 675 Hole Drilled: Present Cps: drlg cmt at 590 ft, hard and slow Operations Summary: install rotating head and associated plumbing. (16.5 hrs) install wear bushing (1 hrs) pu nb #2, 3 dc, tih, tag cmt @ 551 Id excess dp, install rot head and drive bushing on kelly (2.5 hrs) cir out contaminated cmt and mud. Cir until hole cleans up (1.5 hrs) test csg to 1500 psi for 30 min. (0.5 hrs) drlg cmt & float cmt very hard, took 5 hrs to get thru insert float (2 hrs) Comments: Larry Wade w/AOGCC came out to inspect rotating head hook up, he was satisfied that all was in order./cmt is drlg hard due to lenght of set time. GOOD CMT JOB. Spoke with land owner of DD well and all OK will start Icc ASAP. Mud Data: MW: 8.8 Viscosity: 36 Filtrate: 13.2 HTHP Filtrate: 0 Page 4 Well Summary Report Well ID: Pioneer 170215DA Ocean Energy Well Name: Pioneer Unit #1702-15DA 1 O-Aug-99 11 -Aug-99 Surveys: None Days S.S.: 9 Daily Costs: $26,890 Well Costs: $395,212 Current Depth: 935 Hole Drilled: 260 Ave ROP: 21.7 Present Ops: drlg ahead, took survy @ 995- 2 deg Operations Summary: dlr float and cmt 583 - 648 insert float took a long time to drill and cmt very firm (7 hrs) test shoe jts to 850 psi (0.5 hrs) dlr cmt 648 - 675 very firm (1.5 hrs) 675 - 685 10 ft 20 fph (0.5 hrs) perform FIT to 11.8 ppg EMW (1.5 hrs) 685 - 712 27 ft 54 fph (0.5 hfs) lube & service rig (0.5 hrs) 712 -928 216ft 20.57 fph (10.5 hrs) put kelly back into track (1 hrs) 928 - 935 7 ft, 14 fph (0.5 hfs) Comments: geologists not satisfied w/returns going to transfer pit, feel not getting good gas readings, will change flow line tomorrow to rectify. Rept shows no bit info, haven't figured out how to get rim to accept bit. I have it in but can't put in the data. Will get help on that this morning. Mud Data: MW: 9 Viscosity: 37 Filtrate: 12.6 HTHP Filtrate: 0 Surveys: None Days S.S.: 10 Daily Costs: $19,644 Well Costs: $414,856 Current Depth: 1530 Hole Drilled: 595 Present Ops: drlg ahead @ 1650 Operations Summary: 935 - 1027 92 ft, 26.28 fph (3.5 hfs) wireline survey @ 995 - 2 degrees (0.5 hfs) 1027 - 1183 156 ft, 22.28 fph (7 hrs) lube & service rig (0.5 hrs) 1183 - 1530 347 ft, 28.9 fph (12 hrs) wirline survey @ 1499 1.5 deg. (0.5 hfs) Comments: Mud Data: Surveys: None Days S.S,: 11 Ave ROP: 26.4 Harlan Payton Supt. w/CliP leaves today, Duane of CHP arrive today. Hooked up bypasss for gas buster today, when put online the rotating head starting leaking badly. Probably due to square kelly in round hole, will have CHP bring in a 3 1/2 rubber and try that. In the mean time will try to install a sluice box into tranfer pit so can try to get better gas readings. Started to dewater mud so don't have to keep adding fresh water. MW: 9.1 Viscosity: 36 Filtrate: 10.4 HTHP Filtrate: 0 Daily Costs: $44,642 Well Costs: $459,498 Page 5 Well Summary Report Well ID: Pioneer 170215DA Ocean Energy Well Name: Pioneer Unit #1702-15DA 12-Aug-99 13-Aug-99 14-Aug-99 Current Depth: 1811 Hole Drilled: 281 Ave ROP: 24.4 Present Ops: started to drill @ 0400 8-13-99 started out @ 45 fph so will see what continues @ 0445 1839 Operations Summary: 1530 - 1779 249 FT, 22.63 FPH (11 hrs) lube & service rig (0.5 hrs) replace rubber on rotating head (2.5 hrs) 1779- 1811 32 ft, 64 fph (0.5 hrs) rot head bearings lock up. Cir 1/2 hr, pooh 2 hrs, nd rot head 2 hrs, nu new grant shorty rot head (9.5 hrs) Comments: after switching out rot head rubbers, drilled 4 ft and bearings locked up. Decided to pooh and install new rot head. Forgot to have them drop survey. Hole is good condition, no overpull on toh. Pu 2 dc on tih now available bit wt is 31000 Mud Data: MW: 9.4 Viscosity: 37 Filtrate: 10.2 HTHP Filtrate: 0 Surveys: None Days S.S.: 12 Daily Costs: $32,635 Well Costs: $492,133 Current Depth: 2490 Hole Drilled: 679 Ave ROP: 35.7 Present Ops: drlg ahead @ 2569, took survey @ 2500 1 deg, Operations Summary: 2 hr tih, pu 2 dc, 2 hrs ream 90 to bttm. 90 ft fill, bit was plugged when started pump, surge once and then OK. (4 hfs) 1811 - 2094 283 ft, 40.42 fph (7 hrs) cir & survey 2062 1.5 deg (0.5 hrs) 2094 - 2156 62 ft 41.33 fph (1.5 hrs) lube & service rig (0.5 hrs) 2156 - 2490 334 ft, 31.80 fph (10.5 hrs) Comments: all went well this day on operations, trying to keep mud wt down. Using second centrifuge, and keeping up pretty good, seen up to 10 k drag on connections, raising yp and lowering filtrate to 10< lost gen to solids van and trailer units @ 0300, got mud loggers, trailers units on 2nd gen. Locating and waiting for electrician to come and put big gen set back on line. Blew 2 fuses, solids van still down. MW: 9.45 Viscosity: 42 Filtrate: 9.4 HTHP Filtrate: 0 Mud Data: Surveys: None Days S.S,: 13 Daily Costs: $34,285 Well Costs: $526,418 Current Depth: 2905 Hole Drilled: 415 Present Ops: drlg ahead @ 3020 Operations Summary: 2490 - 2527 37 ft, 24.66 fph (1.5 hrs) wireline survey @ 2500 1 deg (0.5 hrs) Ave ROP: 22.4 Page 6 Well Summary Report Well ID: Pioneer 170215DA Ocean Energy Well Name: Pioneer Unit #1702-15DA 15-Aug-99 2527 - 2550 23 ft, 23 fph (1 hrs) lost power on loggers, geologists, & solids control van (1 hrs) 2550 - 2788 238 ft, 26.44 fph (9 hfs) mud loggers data unit down, due to problems w/power gen. Not able to record, hook up micro switch for footage and record gas only. (3.5 hrs) 2788 - 2841 53 ft, 15 fph, (3.5 hrs) install new plug for loggers unit. (0.5 hrs) 2841 - 2905 64 ft, 18.28 fph (3.5 hrs) Comments: mud loggers lost data unit in dog house due to problems with electricial yesterday morning. It appears that the plug to a 60 amp when it was plugged into the small generator, when plugged back into the large generator the plug was not put back to a 100 amp. And was plugged into the availalbe 60 amp plug. Of course the wires were not right and it looks as if the unit got 220 on the common wire instead of the hot wire. Thus had a wrong power feed and cooked the data recorder. The unit was in the rig doghouse but it must have feed through the data lines and bypassed the 2 safety systems in the doghouse. Which is a surge suppessor and fuses. The doghouse also was not grounded and that could have added to the problems. Of course now both problems have been rectified but it is too late. Lesson learned: tell your relief of any changes that were made to equipment. When we switched power, no one was on tour that switched the plugs. If trip will pu a harder bit, have an f-15 on loc Mud Data: MW: 9.6 Viscosity: 43 Filtrate: 8 HTHP Filtrate: 0 Surveys: None Days S.S.: 14 Daily Costs: $17,885 Well Costs: $544,303 Current Depth: 3184 Hole Drilled: 279 Ave ROP: 21.5 Present Ops: testing IBOP @ rt and have upper and lower kelly cock left Operations Summary: 2905 - 3029 124 ft, 24.8 fph (5 hrs) wireline survey @ 2998 1 deg (0.5 hrs) 3029 - 3122 93 ft, 16.9 fph (5.5 hrs) lube & service rig (0.5 hrs) 3122 - 3184 62 ft, 24.8 fph (2.5 hrs) cir bttms up (0.5 hrs) wireline survey @ 3153 1 deg (0.5 hrs) pooh to 3000, tripping block clutch slipping (1.5 hrs) replace clutch plates on tripping block clutch (1 hfs) pooh, 5 - 15 k bobbles (4 hfs) testing bop's, HCR grease fitting blew out on test, ND valve to replace (fitting on bttm side of valve of course!) (2.5 hrs) Comments: mud loggers got new data unit for doghouse, installed and operatonal 0200 hfs 8-16-99 cut mud wt by dilution and w/centrifuge to 9.1 and should get to 8.8 Page 7 Well Summary Report Well ID: Pioneer 170215DA Ocean Energy Well Name: Pioneer Unit #1702-15DA 16-Aug-99 17-Aug-99 when back on bttm HCR valve grease nipple parted when tested. Had to nd HCR to repair. Northern Lights out in force this evening. Mud Data: MW: 9.1 Viscosity: 34 Filtrate: 9.6 HTHP Filtrate: 0 Surveys: None Days S.S.: 15 Daily Costs: $26,164 Well Costs: $570,467 Current Depth: 3329 Hole Drilled: 145 Ave ROP: 26.4 Present Ops: 0400 8-17-99, 3459 rot head locked up, pulling rot head assembly, Operations Summary: test bope 300 Iow, 2000 high, test went well after repairing HCR grease nipple (6 hrs) CDL on kelly block (2 hrs) install wear bushing (0.5 hrs) pu NB #4, tih (3.5 hrs) wash & ream 3064 -3184 washed down but bit was plugged when tried to cir (3 hrs) cir bttms up prior to drilling (0.5 hrs) 3184 - 3277 93 ft 26.57 fph (3.5 hrs) replace rubber and seal on rot head, (3 hrs) 3277 - 3329 52 ft 26 fph (2 hrs) Comments: rot head seal leaking this evening. Replace seal and rubber and all OK. But at 0430 on 8-17-98 rot head locked up. Will have to drill thru transfer pit as no rot head available Mud Data: MW: 9.3 Viscosity: 38 Filtrate: 6 HTHP Filtrate: 0 Surveys: None Days S.S.: 16 Daily Costs: :$24,537 Well Costs: $595,004 Current Depth: 3459 Hole Drilled: 130 Ave ROP: 32.5 Present Ops: @ 0400 just finishing installing rot table Operations Summary: 3329 - 3459 130 ft, 32.5 fph (4 hrs) rotary table locked up, 2 hfs, Id rot head and investigate, found not rot head but table. 2 hrs- investigate tabel and mix & pump hi~.vis pill and spot on bttm. 1 hr pooh to 2400. 3hrs pull drive pinion for rotary table. 5 hr pooh (chain out). 1 hr pull and lay out rotary table. 6 hr clean, tear down & repair rotary table, most of bolts that hold top plate on were broken or missing. Repalce and tighten bolts. Put table back together. (20 hrs) Comments: it appears that wtih the heavy side load (msialigned over hole) that with the top plate being able to move that that was the problem. The ring gear was able to move up and down 1-2 inches causing the clanging & banging. Repalced and tightened the bolts and all appears OK. Can move the table freely by hand and can feel or hear nothing wrong. Mud man cleaned mud tanks while working on rot table. Loc work on 1702-15 DD is progressing nicely. Have most of main pad area done but still working on covering rest of pad with 6 inches of gravel. Am buying gravel from Jake. Still have boo koo (lots) water Page 8 Well Summary Report Well ID: Pioneer 170215DA Ocean Energy Well Name: Pioneer Unit #1702-15DA 18-Aug-99 19-Aug-99 around and on pad. Mud Data: MW: 9.3 Viscosity: 37 Filtrate: 6 HTHP Filtrate: 0 Surveys: None Days S.S.: 17 Daily Costs: $38,078 Well Costs: $633,082 Current Depth: 3459 Hole Drilled: Ave ROP: Present Ops: wait on bearings for swivel Operations Summary: work on rot table, install bolts for top plate, appears to be OK (4.5 hrs) tih, hit birdge @ 3130 (logs show a small coal there) (4 hrs) wash to bttm, after washing thru @ 3130 had no trouble all the way to bttm. Washed only did not rot. On bttms up from 3130 lots of coal then pea size cuttings. Nothing major rest of way in hole and nothing at all BU from td (4 hrs) mix & pump hi-vis sweep, brought nothing back (1 hfs) level rig over hole (0.5 hrs) work on swivel, couldn't get to rotate at all at first, worked on it a little & got it to trun. After watching for 10 min at 25 rpm it's top bearing was hot. Decided to try and drill, made 1/2 foot and swivel was smoking. (2 hfs) pooh to shoe (3.5 hrs) break & Id kelly, Id swivel (1.5 hrs) cont pooh to surface (1.5 hrs) wait on parts for swivel (1.5 hrs) Comments: Matt Rader (DNR) & Faye Sullivan (UNOCAL) visit loc in p.m. Showed them around and they took pictures and then left. They visited the DD and CC loc also. Did not say anthing pro or con about the operation. After getting rig leveled tried to drill but swivel was locked up. Got it turning and tried to drill, got 1 ft and could see smoke pouring out of it. Shut down and started ooh. Mud Data: Surveys: Days S.S.: DD is ready except for dead men. Water well rig got conductor opened up and got down to 42 ft with a 12 1/4 bit so all should be OK. MW: 9.2 Viscosity: 47 Filtrate: 6.8 HTHP Filtrate: 0 None 18 Daily Costs: $11,157 Well Costs: $644,239 Current Depth: 3459 Hole Drilled: Present Ops: wait on swivel, parts arrived late p.m. This date. Operations Summary: wait on parts for swivel. (24 hrs) Mud Data: MW: 9.2 Viscosity: 46 Filtrate: 6.8 Surveys: None Days S.S.: 19 Daily Costs: $9,145 Ave ROP: HTHP Filtrate: 0 Well Costs: $653,384 Page 9 Well Summary Report Well ID: Pioneer 170215DA Ocean Energy Well Name: Pioneer Unit #1702-15DA 20-Aug-99 21 -Aug-99 22-Aug-99 Current Depth: 3459 Hole Drilled: Ave ROP: Present Ops: drlg ahead @ 3532 Operations Summary: wait on swivel (8 hrs) ru swivel and kelly (5 hfs) tih (cir bu 61500 ft), to 2680 (2 hrs) broke slips, hit w/elevators, wait on replacement slips (4 hrs) work on and adjust brakes (2.5 hrs) tih to 3425, w/o problems, install rot head (1.5 hrs) wash 3425-3460, 10 ft fill, cbu (1 hrs) Comments: lost 3 hfs due to not having parts or replacement dp slips. Bringing yp and vis up helped greatly, only 10 ft fill on bttm after 2 1/2 days. No plugged nozzles. Mud Data: MW: 9.2 Viscosity: 51 Filtrate: 7.8 HTHP Filtrate: 0 Surveys: None Days S.S.: 20 Daily Costs: $9,145 Well Costs: $662,529 Current Depth: 3943 Hole Drilled: 484 Ave ROP: 21.0 Present Ops: drlg ahead @ 4000 @ 0400 HRS Operations Summary: 3459 - 3656 197 ft, 21.88 fph (9 hfs) lube & service rig (0.5 hrs) 3656 - 3783 127 ft, 23 fph (5.5 hfs) wirline survey @ 3751 - 1 deg (0.5 hrs) 3783 - 3943 160 ft, 18.8 fph (8.5 hfs) Comments: all going smooth last 24 hrs, will have yp to 16 by TD. Geologists say will probably drill an extra 150 as expect large coal section about 4100 +- Mud Data: MW: 9.3 Viscosity: 51 Filtrate: 6.6 HTHP Filtrate: 0 Surveys: None Days S.S.: 21 Daily Costs: $18,704 Well Costs: $681,233 Current Depth: 4265 Hole Drilled: 322 Ave ROP: 18.9 Present Ops: spot hi -vis pill prior to pooh for logging Operations Summary: 3943 - 4158, 215 ft 18.69 fph (11.5 hrs) lube & service rig (0.5 hrs) 4158 - 4265 107 ft, 19.45 fph TD @ 4265 (5.5 hrs) cir bttms up (1 hfs) pooh to DC, SLM, tite spot 3414-3385, 25 k op, work a couple times then OK. Trip took long because of SLM and trouble with tripping clutch, see comments. SLM 9.64 ft long, no correction (5 hrs) tih (0.5 hrs) Page 10 Well Summary Report Well ID: Pioneer 170215DA Ocean Energy Well Name: Pioneer Unit #1702-15DA 23-Aug-99 24-Aug-99 Comments: Mud Data: Surveys: None Days S.S.: 22 had to work pipe a couple times @ 3414-3385, 25 k op, with rig tripping clutch slipping it was hard to really see how much we would of had to pull. But was able to work thru it and carry on. Having solids control do de-watering when finished drilling and while logging. SLM. 9.64 ft long, no correction. Spoke w/John Spaulding of AOGCC and was waived for weekly bop test because TD and no well control problems. No fill & no problems going backto bttm for short trip. HAD 41 PPM H2S AS SC)ON AS STARTED TO CIR, ALARM AT SHAKER WENT OFF MW: 9.3 Viscosity: 52 Filtrate: 4.8 HTHP Filtrate: 0 Daily Costs: $18,715 Well Costs: $699,948 Current Depth: 4265 Hole Drilled: Ave ROP: Present Ops: logging w/dip meter Operations Summary: cont tih, no fill, (2.5 hrs) cir hole clean, fair amount of small stuff while cir but clean after bttms up (1 hrs) mix hi-vis sweep and spot on bttm (1 hrs) pooh for logs w/o problems (4 hrs) ru Baker Atlas for e-line logging (0.5 hrs) saftey meeting w. BA and all rig personnel. Logging (0.5 hrs) run #1, HDIL-DAL-GR-CAL TD 4237 TEMP 92 DEG. Resistivity toool failed for this run (4 hfs) run #2, LDL-CN- GR- CAL TD 4237 (6.5 hfs) run #3, resistivity tool failure. Both tools failed (4 hfs) Comments: Spoke w/Blair Wondzell about cmt around surfce pipe. He said will not have to perf 9 5/8 but to try and 1" on the outside of 9 5/8. He sent Larry Wade (AOGCC inspector) to loc @ 2030 hrs and we could only get a 1" pipe down about 10 ft. He said that when we nipple down for the rig move to call him and we will try again with the BOP's out of the way. At that time we will probably put in dry cmt around the 9 5/8 to seal it off. Both resistivit;y tools failed, flying one in from the Slope on earliest flight available, should have it here by noon. Dewatering going OK doing aprox 1 bpm. Ave hole size is 9 1/4 inches HTHP Filtrate: 0 Viscosity: 54 Filtrate: 4.8 Daily Costs: $16,615 Well Costs: $716,563 Mud Data: MW: 9.2 Surveys: None Days S.S.: 23 Current Depth: 4265 Hole Drilled: Operations Summary: run#3 cont. Resistivity tool failed, working on tools (2 hrs) run #4, dipmeter, 4237 (6 hrs) Ave ROP: Page 11 Well Summary Report Well ID: Pioneer 170215DA Ocean Energy Well Name: Pioneer Unit #1702-15DA 24-Aug-99 25-Aug-99 26-Aug-99 Comments: all four geologists released until after surface on next hole. Mud Data: MW: 9.3 Viscosity: 51 Filtrate: 4.8 HTHP Filtrate: 0 Surveys: None Days S.S.: 24 Daily Costs: $16,615 Well Costs: $733,178 Current Depth: 4265 Hole Drilled: Ave ROP: Present Ops: running csg Operations Summary: pull wear bushing (0.5 hrs) tih to 4185 (3.5 hrs) washs to bttm 4185-4265 - no fill - precautionary (1 hrs) cir & condtion mud to run csg, fairly heavy returns at shaker but cleaned up nicely at bttms up, spot hi-vis sweep prior to Id dp (2.5 hfs) pooh sideways, (8 hrs) change dp rams to 7" csg rams (0.5 hrs) Comments: Id dp took longer that expected by 2 hrs. Mud Data: MW: 9.3 Viscosity: 51 Filtrate: 4.8 HTHP Filtrate: 0 Surveys: None Days S.S.: Daily Costs: $16,615 Well Costs: $749,793 Current Depth: 4265 Hole Drilled: Ave ROP: Present Ops: getting ready to cmt 2nd stage Operations Summary: cont install 7" csg rams (0.5 hrs) ru & run 103 jts 7" 23# CF-50 LTC 8rd csg (10.5 hrs) cir & cond, drop yp f/20 to 6, vis 52 to 36, wt 9.3 to 8.9 (4.5 hrs) safety meeting, cmting (0.5 hrs) 20 bbls mcs-4 spacer, 11.5 ppg, 515 sx (99 bbl) "G" cmt, 15.8 ppg, dispalce w/168 bbls (102 water, 66 bbls mud), cmt to surface at 100 bbls into displacement (1.5 hrs) drop bomb, open dv @ 800 psi, cir 1 bpm @ 800 psi, lots of clabbered mud and cmt at surface right away. (1.5 hrs) cir & condition mud for next stage, (5 hrs) Mud Data: MW: 8.9 Viscosity: 36 Filtrate: 6.8 HTHP Filtrate: 0 Surveys: None Days S.S.: Daily Costs: $20,582 Well Costs: $770,375 Current Depth: 4265 Hole Drilled: Ave ROP: Present Ops: moving rig Operations Summary: condition mud prior to 2nd stage cmt (4 hfs) cmt 2nd stage 77 bls "G" 12.5 ppg, dispalce w. 74.5 bbls water, cmt to surface at 51 bbls displacement (1 hfs) nd bop, set 7" csg slips w/64, 000 (2 hrs) nd divertoer, bope, (3 hrs) Page 12 Well Summary Report Well ID: Pioneer 170215DA Ocean Energy Well Name: Pioneer Unit #1702-15DA 06-Sep-99 07-Sep-99 install 11" 3M x 7 1/6" 3M tbg spool, test to 2500 psi, install top flange (3 hrs) clean mud tanks, r/d equipment, mud tanks full of contaminated cmt and etc. Using super sucker to clean. Rig released @ midnight 8-26-99 (11 hrs) Comments: released rig @ midnight 8-26-99 Mud Data: None Surveys: None Days S.S.: Daily Costs: $140,461 Well Costs: $910,836 Current Depth: 4265 Hole Drilled: Ave ROP: Present Cps: 9/3 - 9/6/99: Drilling out stage tool. MIRU CH&P drilling rig #19 w/related equipment. NU BOP. Received 140 jts 2-7/8" J-55 EUE tbg. PU 6-1/2" bit, bit sub, two 4-3/4" DC's XO & 57 jts tbg. Tag cement fill @ 1802'. Drill out cement to DV tool @ 1822. Circulate hole clean. SWIFN. Operations Summary: Mud Data: None Surveys: None Days S.S.: Daily Costs: $17,886 Current Depth: 4265 Hole Drilled: Present Cps: Run CBL Operations Summary: Well Costs: $928,722 Ave ROP: Mud Data: None Surveys: None Days S.S.: Daily Costs: $0 Well Costs: $928,722 Printed: 13:00 25-Apr-O0 Page 13 COMPLETION SUMMARY PIONEER UNIT 1702-15DA 9/06/99 9/07/99 9/08/99 9/09/99 9/10/99 9/11/99 9/12/99 9/17/99 10/01/99 MIRU CH&P RIG 19. NU BOPE. PU TBG. DRILL OUT DV TOOL AT 1822'. CIRCULATE HOLE CLEAN. FINISH DRILLING OUT DV TOOL AT 1822'. WASH TO PBTD ~ 4135'. CIRCULATE HOLE CLEAN. POOH W/TBG TO DC'S. LD DC'S. RU ATLAS WIRELINE. RUN CBL FROM 4137' TO 3500' W/0 PSI. REPEAT CBL 4137' TO SURFACE W/500 PSI. FORWARD CBL TO AOGCC (MR. WONDZELL) FOR APPROVAL TO CONTINUE. TEST BOPE AND MANIFLOD AS REQUIRED BY AOGCC (MR. STEIVE). RIH W/TBG AND BIT AND SCRAPER. RECEIVED APPROVAL FROM AOGCC TO PROCEED W/ COMPLETION. CIRCULATE HOLE FROM 4135' W/2% KCL WATER. SWAAB FL TO 2700'. POOH. LD BIT AND SCRAPER. RU ATLAS WIRELINE. PERFORATE 3700-3750' 4 ½" HSC 5 JSPF 43 GRAM CHARGES. LIGHT BLOW AFTER PERFORATING. RUN GUAGE RING. SET BAKER SC1 PACKER AND XN NIPPLE AT 3645' PU BAKER SC1 SEAL ASSEMBLY. RIH W/117 JTS TBG. ROLL HOLE W/2% KCL WATER + 110 GAL CORROSION INHIBITOR. ND BOP. LAND TBG IN PACKER AT 3645'. NU WELLHEAD. TEST ANNULUS TO 2000 PSI. TEST TBG TO 2000 PSI. PUMP OUT TBG PLUG BELOW PACKER W/2200 PSI. SWAB FL TO 2800'. STUCK MANDREL IN X PLUG AT 3643'. PARTED SAND LINE AT SURFACE. ND WELLHEAD NU AND TEST BOPE. POOH W/TBG. RETRIEVE SWAB EQUIPMENT FROM X NIPPLE. RIH W/TBG. ND BOPE. STING INTO PACKER AND LAND TBG. NU WELLHEAD. TEST ANNULUS TO 2000 PSI. RDMO CH&P RIG 19.~ff ~'{~ ~000 Oil& 6as Coos. Commi t SI WAIT FOR FACILITIES. ~aSItlt Ancho----ralle PERFORM INJECTIVITY TEST W/BJ SERVICES. 1 BPM 3830 PSI ¼ BPM 3150 PSI ISIP 3030 PSI 15 MIN SI 2130 PSI. SITP/CP 0/0 PSI. RU ATLAS WIRELINE ADDED ADDITIONAL PERFORATIONS THRU TUBING W/2 1/8" PREDATOR 4 SPF 12 GRAM .22" CHARGES: 4060-80', 3988-98' & 3964-84'. NO INFLUX OF BLOW. SI WAIT ON FACILITIES. 10/11/99 10/12/99 10/13/99 10/20/99 10/21/99 ,-,. 01/29/00 MIRU CH&P RIG 19. RU TO SWAB. SWAB TO X NIPPLE AT 3643'. RECOVERED 21 BBL FLUD. WAIT 1 HR AND MADE 1 ADDITIONAL RUN W/NO FLUD RECOVERY. SITP 25 PSI. RU TO SWAB IFL 3500'. RECOVERED V4 BBL FLUD. RU BJ SERVICES. BD PERFS W/41 BBL 2% KCL WATER + .5% NONIONIC SURFACTANT + 1% EDTA. 1.8 BPM @ 3100 PSI. ISIP 2750 PSI 15 MIN 2080 PSI. BD AND SWAB. RECOVERED 30 BBL OF 41 BBL LOAD. FFL 3500'. SITP 10 PSI. SWAB IFL 2750'. RECOVERED 6 BBL FLUD. RDMO CH&P RIG 19. MIRU R&K INDUSTRIAL PUMP FOR INJECTIVITY TEST. PUMPED 500 BBL PRODUCED WATER. FINAL RATE 1.7 BPM ~ 2850 PSI. TEST ANNULUS TO 1520 PSI FOR 30 MINUTES W/NO LEAKOFF. REPORT RESULTS OF TEST TO AOGCC. CONTINUE INJECTIVITY TEST. PUMPED 650 BBL FLUD. FINAL RATE 2BPM 2650 PSI. SECURED WELLHEAD W/CHAINS AND LOCKS. INSTALLED WELLHEAD SHELTER. SI WAIT ON PRODUCTION. OCEAN ENERGY RESOURCES, INC. DALLY RIG REPORT Well: PIONEER UNIT #1702-15DA Peris: N/A Location: SEC 15 T17N R2W TD/PBTD: 4137' Date: 10/25/99 KB/GL 276'/265' Work Done on: Others: PKR (~ 3645' Present Operation: SI WAIT ON FACILITIES Peris: 3700-3750' 3964-3984' Operations Planned: 3988-3998' 4060~080' Time From To DAILY OPERATIONS 10/21/99 - TEST CASING ANNULUS TO 1520 PSI FOR 30 MINUTES W/NO LEAKOFF REPORT RESULTS OF TEST TO AOGCC. DISPOSED OF 650 BBL FLUID 10/22/99 DISPOSED OF 700 BBL FLUID 2 BPM 2650 PSI [. 10/23/99 i' DISPOSED OF 700 BBL FLUID t 2 BPM 2450 PSI 1.5 BPM 240'0 PSI 1 BPM 2.350 PSI ' i0/24/99 ~. DISPOSED OF 250 BBL FEuiD , '"' ' 2 BPM 2450' PSI COSTS PREVIOUS DALLY CUMULATIVE Rig $44,8971 $0~ $44,897 supervision .. $10,500: ' $750: ' $11,250 Rentals ...... $4,000 $1,.000 $5,000 Roustabouts $2,400 $0 $2,400 Transportation ' ' . .... $5,,850 $0 $5,850 Cement, Acid, Frac. .... $2,833 $0 $2,833 Perforating, Logging, $13,768 $0 $13,768 Subsurface PumPs $0 Rods, Scrapers ,. $01 Tubin9, Subs, SN $0 TA.C, Packer, P,"epair ., $27,~t41 $0 .., $27,441 Others $0 Location $750 $0 $750 ,. Misc. $1,100 $0 $1,100 Electrical $0 Water " $3,482 ,. $6,500 $9,982 Contingency $11,702 $825 $12,527 TOTAL $128,723 $9,075 $137,798 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY ' REPORT 20 AA[3 25.432 Name of (~Perator' J ' - Field and Pool - Month and Year of'Injection 1. WELL 2. APl NUMBER 3. u~ 4. FIELD 5. TUB!NG PRESSURE CASIN.,G PRESSURE DAILY AVERAGE INJECTION TOTAl_ MONTPI-Y II~JECTION NO. 50-- u) & POOL ~DAYS 6. MAX 7. AVERAGE 8.-MAX 9. AVERAGE 10. LIQUID 11. GAS 12. LIQUID 13. GAS ~ CODE IN PSIG PSIG PSIG PSIG (BBL) (MCF) (BBL) (MCF) o 'OPER i~/0~_-i51)1~ 5~)-toq- W q ~(~SD 2500 T~s~e~ ~in,~ ~~ 0 ~00 0 I hereby certify that the foregoing is true and correct to the best of my knowledge 14. . -, - Form 10-406 Rev. 12-1-85 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY .0';,spo~ REPORT 20 AAC 25.432 ,, · Name of Operator' J Fiel~l and Pool Monlh and Year of 'Injection 1. WELL 2. APl NUMBER 3. 4. FIELD 5. TUBI.NG PRESSURE CASING PRESSURE DAILY AV.fiRAGE INJ.~CT!O~ TOTAL MON. THLY INJEGTION NO. 50-- ~ I POOL DAYS 6. MAX 7. AVERAGE 8. MAX ~. AVERAGE 10. LIQUID 11. GAS 12. LIQUID 13. GAS ~ CODE IN PSIG PSIG PSIG PSIG (BBL) (MCF) (BBL) (MCF) o OPER I~O~-I~ph 5~-~q- M q ~%b 2500 T~e~se~ , %~n~,~,p,; ~~ O X~OL) o Sign~~lhereb~t,h~h~f°reg°ingistrueanOc°rrectt°thebest°fmykn°wleOge~ ~d - / ~'¢~ ~' 14' Title 9~~Xeg~ ~ ~'~ L~,[ ...... Date ~' ~ ~ TOTAL , - Form 10-406 Rev. 12-1-85 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate APR--O~--00 81 ))? P~ P.01 April 6, 2000 Mr, I~.ober! P, Crandoll Senior Petroleum.Geologist 3(.101 Porcupiae Drive Anchorage, Alaska 99501.3192 Mr, Crandntl: I am in receipt ofyour leller dnled April 4,200t), I am currently working on 5,our requests. The one thing 1 would like to claril~ is that OEI has not commenced i~kicction operations into well 15DA WDW, All ol'ti~e wells mentioned in you letter are currently shul in until sometime in lhe spring when we will commence completion operntions, ] have been in contact with Chuck Wilson our Drilling Supervisor to collect tile addition:~l data the! you are requesting. A l~rgc portion of the data tl'll, lSl come l'rolll our geological department and will come oul of Houston. Chuck is currently in the process of'contacting th~m to help tis gather tl~Js information. I have made it clem' to Mr. Wilson that thc State of Alaska is growing impatient and that we are overdue in our requirements. Fie will relay this to i..Iouslon nnd ask thenl lo f'orward lhe requested items to the Newcastle office so we can make every effort to see that )'ou receive all itvms that you have requests:d. 1 have in our files the daily drilling and operations history, I will copy and forward these items immediately as well as the two lacking compMion reports and tile logs on the BLT #1 and 15DA WDW. I apologize tbr nil of ll'~e contbsion and thank you For you cooperation. Sincerely, Lor~tta Murphy ?roduction Analyst Larry Curl is N~wcaslle Area Foreman Oa~n Et~el~¥, Irle. #7 ('i-iiIl.l'-k,t ! '}Five P,{ ). I].ox ,'~tt) NeWc, vqle, Wyomillg 82701 (])7) 7~-~)52 I:nx: fflOT) 746.404~ ALASKA OIL AND GAS CONSERVATION CO~IISSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 April 4. 2000 Ms. Loretta Murphy, Production Analyst Ocean Energy 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 ! 999, Ocean Energy Rcsourccs. Inc. (OER) received permits to drill the 15DA WDW? i 4CC, and 15DD wells within the Pioneer Unit near Wasilla, Alaska. OER also received a permit to re-drill and recomplcte thc ARCO BLT #1 well within this same unit. It is the Alaska Oil and Gas Conservation Commission's (AOGCC's) understanding that operations were conducted 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 each of these wells within 30 days after completion, abandonment, or suspension. Additionally, fluids injected into wells must be reported according to 20 AAC 25.420 and 20 AAC 25.432. We have rcccivcd reports that OER has commenced injection operations into well 15DA WDW. According to our records. OER has not complied with these regulations, having only submitted incomplete information on two wells. Your cooperation is required to bring OER into compliance with Alaska regulations. Your response to this letter will dctcnninc thc actions we will undertake in reaction to these regulatory. violations. hfformation 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 (Permit to Drill Number 99-064): Completion Report (Form 10-407) Geologic markers cncountcrcd (name, measured depth and true vertical depth of each marker) Daily drilling and operations history' Sepia and reproduced copies of all logs run Digital data and verification listings for all logs run (on diskette or tape) Data m~d reports for production tests, drill stem tests or other formation tests (if conducted) Samples and laboratoD' analytical results from conventional and sidewall cores (if obtained) Geochemical and formation fluid analyses (if obtained) Monthly Injection Report (Form 10-4()6) for thc months thc well was used for disposal purposes. Ms. Loretta Murphy ( 2 ~'{ Ocean Energ3~ Resources Inc. April 4. 2000 Pionccr 1. 2. 3. 4. 5. 6. Unit 14CC (Permit to Drill Number 99-065): Daily drilling and operations history Scpia copies of all logs run Digital data and vcrification listings for all logs run (on diskcttc or tape) Data and repons for production tests, drill stem tests or other formation tests (if conducted) Samples and laboratorx' analytical results from convcntional and sidcwail corcs (if obtaincd) Geochemical and formation fluid analyses (if obtained) Pioneer 1. Unit 15DD (Permit to Drill Number 99-066): Geologic markers encountered (name. measured depth and truc vertical dcpth of each marker) 2. Dailv drilling and operations history 3. Sepia copies of all logs run 4. Digital data and vcrification listings for all logs run (on diskette or tape) 5. Data and repons for production tests, drill stem tests or other formation tests (if conducted) 6. Samples and laboratorx' analytical results from conventional and sidewall cores (if obtained) 7. Geochemical and formation fluid analyses (if obtained) Pioneer I. 2. Unit BLT #1 (Permit to Drill Number 99-068): Completion Report (Form 10-407) Geologic markers encountered (name, measured depth and true vertical dcpth 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 repons for production tests, drill stem tests or other formation tests (if 7. Geochemical and formation fluid analyses (if obtained) conductcd) A cop).' of the AOGCC's regulations is attached for your review. A prompt reply to this notification is cxpcctcd. If you have any questions, please contact or Steve Davies or me at (907) 279-1433. Sincerely. Robert P. Crm~dall Senior Petroleum Geologist Attachment: Alaska Oil and Gas Conservation Commission Regulations. November 7. 1999 cc: Commissioner Seamount PlOli' -~R UNIT FLUID SAMPLE ANALYSIS l'"' 111219 9 COMPONENT UN IT BASE #1 #2 ¢k31 t#-4 #5 , 9920 8690 59601 7850~ 4990 CHLORIDE , mc.:j/I .... SULFATE mg/I 25 37.2 27.8i 26.31 2.35 MAGNESIUM mg/i 6.86 32.5 34.7 0.1 !,6 18 CALCIUM mcj/I 65.8 578 ,, 629 8.6 100 , SODIUM mg/i , .1250 4080 3860 330 2830 BARIUM 'mg/I 8.991 19.1 18.6 0.0302 7.36J IRON " mg/I 0.373 53.7 118 0.162 0.05 POTASSIUM .. mg/I 9830 930 805 6760 1091 PH !13h units 7.8i 7.941 8.06 9.63 7.56, HARDNESSasCaco3 'mcj/I 192, 15801 1710 , 22 324, Sp. Gr. 'SpG(~25c.! 1.018~ 1.013i 1.01.5 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 10107199 1702-15DD SWAB SAMPLE ZONES 4052-62'4010-14' DARK RED WATER W/3% BS. ANALYSIS DONE W/FILTERED SAMPLE. #2 10/11/99 1702-15DD SWAB SAMPLE ZONES3748-56' 3884-90' 3916-22' DARK RED WATER 2% BS #3 10/13/99 10/18/99 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 SEP- 9-88 THU 8'25 PM 0 CF,~,NI-EI~IBGRY, AK FAX HO, mQ7 37.2 1038 P. ,I __ :._/ Ill II .... __ J[ il .... ' I I! .... ! I1 l, : It . i ~l il ,~1 il .;f i 1 ~ I t ~ I I ] {~ I1 I ~ II i ~ ~ II ~ ~ I1 ~ .Il [ iI ~ ~II~ I I ] ~ ~ I I ~- i J II lll: ~ ! ~ f [.iii ~ C~ ...... .... ~ll~l l.I I! ~] _~ _.~ .... 1.: . ~ ~l~ I.l. ~'-~ ' 1 iii Il _ ...... . ~ lll~ ! I .... m~l ..il I I I I II II Ill I I I I I' I l i · I II ill ....... l_l__l_i_Ii_[ .,, i, , i .... /-,'- ....~__ r-, OCEAN ENERGY RESOURCES, INC. DALLY RIG REPORT Well: PIONEER UNIT #1702-15DA Perfs: N/A Location: SEC 15 T17N R2W TD/PBTD: 4137' Date: 10/25/99 KB/GL 276'/265' Work Done on: Others: PKR (~ 3645' Present Operation: SI WAIT ON FACILITIES Perfs: 3700-3750' 3964-3984' Operations Planned: 3988-3998' 4060~080' Time From To DAILY OPERATIONS -- 10/21/99 ,. - TEST CASING ANNULUS TO 1520 PSI FOR 30 MINUTES W/NO LEAKOFF REPORT RESULTS OF TEST TO AOGCC. DISPOSED OF 650 BBL FLUID , . , I10/22/99 -- ,, DISPOSED OF 700 BBL FLUID .., 2 BPM 265O PSI ,w, 10/23/99 ~ ., DISPOSED OF 700 BBL FLUID 2 I~PM 2450 PSI 1.5 BPM 2400 PSI 1 BPM' 2350 PSI ...... 10/24/99 ,, , ,, I .... DISPOSED 'OF 250 BBL FLUID 2 BPM 2450 PSI .... ,, ...... COSTS PREVIOUS DAILY CUMULATIVE Rig $44,897 $0 $44,8971 Supervision " $10,500 $750 '" $11,250 Rentals $4,000 $1,000 $5,0001 Roustabouts $2,400 $0 $2,"40.'0! ,, Transporta.tion ...... $5,850 $0 $5,850 Cement, Acid, Frac. $2,833 $0 $2,833 Perforating, Logging ...... $13,768 $0 '$13,'76'8 ,, , Subsurface Pumps ..... $0 Rods, Scrapers ' ... $0 Tubin~], Subs, SN $0 ]'AC, Packer, Repai'r " $27,441 $0 '$27,441 2thers $0 _ocation $750 .... $0 $75© Vlisc. $1,100 $0 $!,10'0 F.¥'eCtrical " $0 Nater . . $3,482 $6,500 $~.,98~ .3.ontin g en cy _ $11,702 $825 $12,527 TOTAL $128,7~3 $9,0751 $137..,79.8 OCEAN E N E RGY . sou.c s. ,.c. DAILY RIG REPORT Well: PIONEER UNIT #1702-15DA Peris: Location: SEC 15 T17N R2W TD/PBTD: Date: 10/21/99 KB/GL Work Done on: 10/20/99 Others: Present Operation: DISPOSING OF AFFLUENT WATER Peris: N/A 4137' 276'/265' PKR (~ 3645' 3700-3750' 3964-3984' Operations Planned: 3988-3998' 4060~080' Time From To DAILY OPERATIONS 10~20~99 MIRU R&K INDUSTRIAL PUMP AND TANK BEGIN INJECTION OF DRILLING AFFLUENT WATER ESTABLISHED INJECTION AT 1 BPM 2850 PSI PUMPED 500 BBL FLUID FINAL INJECTION 1.65 BPM 2850 PSI. SWIFN COSTS PREVIOUS DAILY CUMULATIVE ]Ri9 $44,897 $0 $44,897 Supervision $10,500 $0 $10,500 Rentals $4,000 $1,000 $5,000 Roustabouts $2,400 $0 $2,400 Transportation $5,200 $650 $5,850 Cement, Acid, Frac. $2,833 $0 $2,833 Perforating, Logging $13,768 $0 $13,768 Subsurface Pumps $0 Rods, Scrapers $0 Tubing, Subs, SN $0 TAC, Packer, Repair $27,441 $0 $27,441 Others $0 .,, Location $750 $0 $750 Misc. $1,100 $0 $1,100 Electrical $0 Water $2,730 $752 .$3,482 .Contingency $11,562 $2401 $11,802 TOTAL $127,181 $2,642! $1.29,823 OCEAN ENERGY Well: PIONEER UNIT #1702-15DA Location: SEC 15 T17N R2W Date: 10/14/99 Work Done on: 10/13/99 Present Operation: SI WAIT ON FACILITIES Perfs: TD/PBTD: KB/GL Others: Perfs: DAILY RIG REPORT N/A 4137' 276'/265' PKR (~ 3645' 3700-3750' 3964-3984' Operations Planned: 3988-3998' 4060~080' Time From To DAILY OPERATIONS 10/13/99 SITP 10 PSI BD TBG RU TO SWAB ,,. IFL 2950' 500' FLUID ENTRY RECOVERED 3 BBL FLUID MADE 1 RUN/HR FOR 4 HRS. RECOVERED 2.8 BBL ADDITIONAL FLUID SWI. ., RDMO CH&P RIG 19 ,, ,, .., ,. _ , COSTS PREVIOUS DALLY CUMULATIVE Rig $41,897 $3,000 $44,897 Supervision $9,7501 $750 $10,500 Rentals $3,400 $600 $4,000 Rousta bouts $2,400 $0 $2,400 Transportation $5,200 $0 $5,200 Cement, Acid, Frac. $2,833 $0 $2,833 Perforating, Logging $13,768 $0 $13,768 Subsurface Pumps $0 Rods, Scrapers $0 Tubing, Subs, SN $0 TAC, Packer, Repair $27,441 $0 $27,441 Others $0 Location $750 $0 $750 Misc. $1,100 $0 $1,100 Electrical $0 Water $2,730 $450 $,3,180i Contingency $11,127 $480 $11,607 TOTAL $122,396 $5,280 $127,676 ,, , OCEAN ENERGY . sou.c s. ,.o. DALLY RIG REPORT Well: PIONEER UNIT #1702-15DA Perfs: Location: SEC 15 T17N R2W TD/PBTD: Date: 10/13/99 KB/GL Work Done on: 10/12/99 Others: Present Operation: SWAB TEST INJECTION PERFS Perfs: N/A 4137' 276'/265' PKR (~ 3645' 3700-3750' 3964-3984' Operations Planned: 3988-3998' 4060~080' Time From To DAILY OPERATIONS 10/12/99 SITP 25 PSI BD TBG RU TO SWAB ,,, IFL 3500' RECOVERED 3/4 BBL FLUID BD W/2% KCL WATER AND RIG PUMP FILL TBG W/21 BBL 2% KCL WATER + .5% F40 SURFACTANT AND 1% U42 EDTA INITIAL INJECTION 1/4 BPM 2450 PSI INCREASE RATE 2800 PSI @ .7 BPM 2950 PSI @ 1 BPM 3100 PSI (~ 1.8 BPM PUMPED 20 BBL ADDITIONAL FLUID. FINAL INJECTION 1.8 BPM 3100 PSI ISIP 2750 PSI 5 MIN 2380 PSI 10 MIN 2150 PSI 15 MIN 2080 PSI BLED BACK IN 2 MINUTES RU TO SWAB. SWAB TO XN NIPPLE (~ 3645' IN 5 RUNS. RECOVERED 25 BBL FLUID MADE 1 RUN/HR FOR 5 HRS. RECOVERED 4.5 BBL FLUID 29.5BBL OF 41 BBL LOAD RECOVERED SWIFN. COSTS PREVIOUS DAILY CUMULATIVE Rig $38,147 $3,750 $41,8971 Supervision $9,000 $750 $9,7501 Rentals $2,800 $600 $3,400 Roustabouts $2,400 $0 $2,4001 Transportation $5,200 $0 $5,200 Cement, Acid, Frac. $2,833 $0 $2,833 Perforating, Logging $13,768 $0 $13,7681 Subsurface Pumps $0' Rods, Scrapers $01 Tubin~h Subs, SN $0! TAC, Packer, Repair $27,441 $0 $27,441 Others $0 Location $750 $0 $750= Misc. $1,100 $0 $1,1001 Electrical $0! Water $2,220 $5101 $2,730 Contingency $10,566 $561 $11,127 TOTAL $116,225 $6,171 $122,396; OCEAN ENERGY .ESOU.C S, INC. DALLY RIG REPORT Well: PIONEER UNIT #1702-15DA Perfs: Location: SEC 15 T17N R2W TD/PBTD: Date: 10/12/99 KB/GL Work Done on: 10/11/99 Others: Present Operation: SWAB TEST INJECTION PERFS Perfs: N/A 4137' 276'~265' PKR (~ 3645' 3700-3750' 3964-3984' Operations Planned: 3988-3998' 4060-4080' Time From To DAILY OPERATIONS 10/11/99 MIRU CH&P RIG 19 RU SWAB EQUIPMENT SITP 380 PSI SWAB TO XN NIPPLE (~ 3645' IN 3 RUNS RECOVERED 21 BBL FLUID MADE 1 ADDITIONAL RUN W/NO RECOVERY SWIFN COSTS PREVIOUS DAILY CUMULATIVE R. ig $35,897~ $2,250 $38,147 S u pervision $9,000 $0 $9,000 Rentals $2,200: $600 $2,800 Roustabouts $1,200 $1,200 $2,400 Transportation $1,700 $3,500 $5,200 Cement, Acid, Frac. $2,833 $0 $2,833 Perforating, Logging $13,768 $0' $13,768 Subsurface Pumps $0 ~ods, Scrapers $0 Tubing, Subs, SN $0 TAC, Packer, Repair $27,441 $0 $27,441 Others $0 Location $750 $0 $750 Misc. $1,100 $0 $1,100 Electrical $0 Water $2,220 $0 $2,220 ~3ontingency $9,811 $755 $10,566 ~ TOTAL $107,920 $8,305 $116,225, OCEAN ENERGY DALLY RIG REPORT Well: PIONEER UNIT #1702-15DA Perfs: Location: SEC 15 T17N R2W TD/PBTD: Date: 10/8/99 KBIGL Work Done on: 10/7/99 Others: Present Operation: SI WAIT ON FACILITIES N/A 4137' 276'/265' Operations Planned: Time From To DAILY OPERATIONS CHECK WELLHEAD PRESSURE SITP 370 PSI COSTS PREVIOUS DAILY CUMULATIVE Rig $35,897 $0 $35,897 Supervision $9,000 $0 $9,000 Rentals $2,200 $0 $2,200 Roustabouts $1,200 $0 $1,200 Tra n sportation $1,700 $0 $1,700 Cement, Acid, Frac. $2,833 $0 $2,833 Perforating, Logging] $13,7681 $0 $13,768 Subsurface Pumps $0 Rods, Scrapers $0 Tubin9, Subs, SN $0 TAC, Packer, Repair $27,441 $0 $27,441 Others $0 Location $750 $0 $750 Misc. $1,100 $0 $1,100 Electrical $0 Water $2,220 $0 $2,220 _Contingency $9,811 $0 $9,811 TOTAL $107,920 $01 $107,920 OCEAN ENERGY DAILY RIG REPORT Well: PIONEER UNIT #1702-15DA Perfs: Location: SEC 15 T17N R2W TD/PBTD: Date: 9/18/99 KB/GL Work Done on: 9/17/99 Others: Present Operation: SI WAIT ON FACILITIES N/A 4137' 276'/265' Operations Planned: Time From To DAILY OPERATIONS 9/17/99 RU BJ SERVICES PUMP TRUCK PRESSURE ANNULUS TO 1200 PSI HOLD AND MONITOR PRESSURE. PUMP DOWN TBG WITH 20 BBL 2% KCL WATER W/SURFACTANT INITIAL PUMP IN PRESSURE 1/4 BPM 3600 PSI GRADUALLY INCREASE RATE AS PRESSURE DECREASED FINAL PUMP IN I BPM AT 3830 PSI DECREASE RATE TO 3/4 BPM AT 3650 PSI DECREASE RATE TO 1/2 BPM AT 3350 PSI DECREASE RATE TO 1/4 BPM AT 3150 PSI SHUT DOWN ISIP 3030 PSI 5 MIN 2436 PSI 10 MINUTE 2218 PSI 15 MINUTE 2130 PSI BLED BACK PRESSURE. SI WAIT ON FACILITIES COSTS PREVIOUS DAILY CUMULATIVE iRig $35,8971 $0 $35,897 ,Supervision $9,000 $0 $9,000 Rentals $2,200 $0 $2,200 Roustabouts $1,2001 $0 $1,200 Tra n s portation $1,7001 $0 $1,700 Cement, Acid, Frac. $2,833 $2,.833 Perforating, Logging $13,768{ $0 $13,768 Subsurface Pumps $0 Rods, Scrapers , $0 Tubing, Subs, SN $0 TAC, Packe~r, Repair $27,441 $0 $27,441 Others $0 Location $750 $0 $750 Misc. $1,100 $0 $1,100 Electrical $0 Water $1,970 $250 $2','220 Conting~'nc¥ $9,503 $308 $9~811 TOTAL $104,529 $3,391 $.107,920 OCEAN ENERGY DALLY RIG REPORT Well: PIONEER UNIT #1702-15DA Perfs: Location: SEC 15 T17N R2W TD/PBTD: Date: 9/13/99 KB/GL Work Done on: 9/12/99 Others: Present Operation: SI WAIT ON FACILITIES N/A 4137' 276'/265' Operations Planned: Time From To DAILY OPERATIONS 9/12/99 ND BOPE LAND TBG AT IN PACKER AT 3645'. NU WELLHEAD. SWI WAIT ON FACILITIES RDMO SERVICE UNIT. COSTS PREVIOUS DALLY CUMULATIVE Rig $32,897 $3,000: $35,897' Supervision $8,250 $750 $9,000 Rentals $1,800 $400 $2,200 Roustabouts $1,200 $0 $1,200 T ran s po rtation $1,700 $0 $1,700 Cement, Acid, Frac. $0 $0 Perforating, Logging $13,768 $0 $13,768 Subsurface Pumps $0 Rods, Scrapers $0 Tubing, Subs, SN $0 TAC, Packer, Repair $27,441 $0 $27,441 Others $0 Location $750 $0 $750 Misc. $1,100 $0 $1,.!00 Electrical $0 Water $1,970 $0 $1,970 ; Conti ng enc¥ $9,088 $415 $9,503 TOTAL $99,964 $4,565 $.104,529 OCEAN ENERGY DALLY RIG REPORT Well: PIONEER UNIT #1702-15DA Perfs: Location: SEC 15 T17N R2W TD/PBTD: Date: 9/12/99 KB/GL Work Done on: 9/11/99 Others: Present Operation: LAND TBG AND TEST ANNULUS N/A 4137' 276'/265' Operations Planned: INJECTIVITY TEST ,i Time From To DAILY OPERATIONS 9/11/99 ND WELLHEAD NU BOPE .POOH W/TUBING, CUTTING SANDLINE OUT OF TUBING iRETRIEVE SWAB EQUIPMENT FROM X NIPPLE. iRIH W/SEAL ASSEMBLY AND TUBING SWIFN. ,, COSTS PREVIOUS DAILY CUMULATIVE Rig $28,397 $4,500 $32,897 Supervision $7,500i $750 $8,250 Rentals $1,800 $400 $2,200 Roustabouts $1,200 $0 $1,200 Transportation .. $1,700 $0 $1,700 !Cement, Acid, Frac. $0 $0 Perforating, Logging $13,768 $0 $13,768 . Subsurface pumps $0 Rods, Scrapers $0 Tubing, Subs, SN $0 TAC, Packer, Repair $27,441 $0 $2.7,441 Others $0 Location $750 $0 $750 Misc. '" $1,100 $0 $1,100 Electrical $0 Water $1,970 $0 $1,970 contingency $8,563 $565 $9,128 TOTAL $94,189 $6,215 $10.0,404 OCEAN ENERGY DAILY RIG REPORT Well: Location: Date: Work Done on: Present Operation: PIONEER UNIT #1702-15DA Perfs: SEC 15 T17N R2W TD/PBTD: 9/11/99 9/10/99 KB/GL Others: PULL TBG TO RETRIEVE SWAB EQUIPMENT N/A 4137' 276'/265' Operations Planned: INJECTIVITY TEST Time From To DAILY OPERATIONS 9/10~99 LD 14 JTS 2 7/8 TBG. PU BAKER OIL TOOLS SEAL ASSEMBLY AND RIH WITH 117 JTS 2 7~8" TBG. ROLL HOLE WITH 120 BBL 2% KCL WATER W/110 GALLON CORROSION INHIBITOR. ND BOP. LAND TBG IN PACKER AT 3645'. TEST ANNULUS TO 2000 PSI. TEST TUBING TO 2000 PSI. PUMP OUT TUBING PLUG BELOW PACKER W/2200 PSI . RU SWAB EQUIPMENT. SWAB TBG DOWN TO 2800'. STUCK SWAB MANDREL IN X NIPPLE AT 3643'. WORK SAND LINE TI FREE SWAB EQUIPMENT. LINE PARTED AT SURFACE. SWIFN. .,. ~.. COSTS PREVIOUS DAILY CUMULATIVE Rig $24,647 $3,750 $28,397 s u pervision $6,750 $750~ $7,500 Rentals $1,400 $400 $1,800 Roustabouts $1,200 $0: $1,200 Tran s portation $1,350 $350 $1,700 Cement, Acid, Frac. $0 $0 Perforating, Logging CORRECTED $9,553 $4,215 $13,768 Subsurface Pumps $0 .Rods, Scrapers $0 Tubing, Subs, SN $0 TAC, Packer, Repair $27,441 $27,441 Others $0 Location $750 $0 $750' Misc. PACKER FLUID $1,100 $1,100~ Electrical $0 _ Water $1,520 $450 $1,970..' Contingency $4,717 $3,846 $8,563 TOTAL $51,887., $42,302 $94,189 OCEAN ENERGY DALLY RIG REPORT Well: PIONEER UNIT #1702-15DA Perfs: Location: SEC 15 T17N R2W TD/PBTD: Date: 9/10/99 KB/GL Work Done on: 9/9/99 Others: Present Operation: TIH W/TUBING AND SEAL ASSEMBLY N/A 4137' 276'/265' Operations Planned' SWAB TEST WEL ., Time From To DAILY OPERATIONS 9/9/99 .. COMMUNICATED W/BLAIR WONDZELL ~ AOGCC CONCERNING BOND LOG. RECEIVED APPROVAL FROM AOGCC TO PROCEED W/COMPLETION OPERATIONS. FINISHED TIH W/TBG TO 4130' CIRCULATE HOLE W/2% KCL WATER RU SWAB EQUIPMENT. SWAB FL TO ESTIMATED DEPTH OF 2700'. POOH W/TBG. LD BIT AND SCRAPER RU BAKER ATLAS WIRELINE EQUIPMENT. IFL 2300' WIRELINE DEPTH PERFORATE 3700' TO 3750' IN 3 RUNS W/4 1/2' HSC 5 JSPF 43 GRAM SHOTS.250 TOTAL SHOTS LIGHT BLOW AFTER 1ST GUN FIRED. BLOW DIED IN 3 MINUTES. FFL 1550' WIRELINE DEPTH. RIH W/6.06" GUAGE RING AND JUNK BASKET TO 3700'. PU BAKER SCl PACKER W/2.313 XN NIPPLE, 6' 2 7/8" SUB AND PUMP OUT PLUG. - RIH AND SET PACKER FROM 3645' TO 3651'. RD BAKER ATLAS. ,., SWIFN. ., ,.,,,, ,,., COSTS PREVIOUS DAILY CUMULATIVE 'Rig $18,272 $6,3751 $24,647 S u pervision $6,000 $750 $6,750 Rentals $1,000 $400, $1,400 RoustaboutS' $1,200 $0~ $1,200 ,, Tra n s po rtation $1,000 $350 $1,350 Cement, Acid, Frac. $0 $0 Perforating, Logging ESTI MATE $2,753 $6,800 $9,553 Subsurface ,,Pumps $0 Rods, Scrapers $0 .Tubing, Subs, SN $0 TAC, Packer, Repai'..r, $0 Others $0 Location $750 $0 $750 Misc. $0 Electrical $0 Water $1,010 $510 $1,520 Contingency $3,199 $1,519 $4,717 TOTAL $35,184 $16,704 $51,887 OCEAN ENERGY RESOURCES, INC. DALLY RIG REPORT Well: PIONEER UNIT #1702-15DA Perfs: Location: SEC 15 T17N R2W TD/PBTD: Date: 9/9/99 KB/GL Work Done on: 9/8/99 Others: Present Operation: SWAB DOWN CASING. N/A 4137' 276'/265' Operations Planned: PREP TO PERFORATE Time From To .DAILY OPERATIONS 9/8/99 '" LD DRILL COLLARS =RU BAKER ATLAS WlRELINE EQUIPMENT RUN SBT BOND LOG FROM PBTD @ 4137' TO 3500' W/0 PSI. REPEA¥ SBT BOND LOG FROM PBTD TO SURFACE W/500 PSI ON CASING. COMMUNICATED W/BLAIR WONDZELL @ AOGCC CONC'ERNING BOND LOG. RECEIVED VERBAL APPROVAL TO PROCEED WITH PERFORATING PREPEI~ATIONS PENDING REVIEW OF LOG. RU TO PRESSURE TEST BOP AND MANIFOLD AS REQUIREI~ BY AOGCC TEST BLIND RAMS AND CASING TO 300 & 2000 PSI TEST MANIFOLD VALVES TO 300 & 2000 PSI. .... VERIFY BOTH CHOKES WERE OPERATIONAL. ,,, RIH W/BIT AND CASING SCRAPER TO 500' SECURE TUBING. TEST TIW VALVE AND PIPE RAMS TO 300 & 1500 PSI. TEST WITNESSED AND APPROVED BY CHUCK STEIVE, AOGCC INSPECTOR. RIH W/REMAINING TUBING. SWIFN. ,,, , ,, ,, , , , , COSTS PREVIOUS DAILY CUMULATIVE Rig $'i'3,822 $4,450 $18,272 Supervision ,,, $5,250 $750 . $6,000 Rentals $600 $400 $1,000 R~ustabou'ts "' $1,200 $0 $1,200 Tra n s po rtation $650 $350 $1,000 Cemen.t, Acid,,, Frac. $0 $0 Perforating, Log~lin9 $2,753 $2,753 ~Subsurface Pumps , $0; Rods, Scrapers $0 Tubing, Subs, ,SN $0 ~TAC, Packer, Repair $0i Others $0 ,, ,, , Location $750 $0 $7501 Misc. $0; Electrical $0 Water .... $560 $45'~ $1,01 0 C. onti n genc¥ $2,283 $915 $3,,199 TOTAL $25,115 $10,068 $35,184 OCEAN ENERGY RESOURCES, INC. DALLY RIG REPORT Well: PIONEER UNIT #1702-15DA Perfs: Location: SEC 15 T17N R2W TD/PBTD: Date: 9/8/99 KB/GL Work Done on: 9/7/99 Others: Present Operation: RUN CBL N/A 4135' 276'/265' Operations Planned: PREP TO PERFQRATE Time From T° DAILY OPERATIONS 9/7/99 -- DRILL OUT DV TOOL AT 1822'. PU 2 7/8" TBG TAG CEMENT FILL AT 4120' RU SWIVEL AND WASH DOWN TO 4135'. DRILLING HARD CEMENT AT 4130' CIRCULATE HOLE CLEAN. r" TOOH W/ TBG TO DRILL COLLARS. ' ......... SWIFN. , , .. , .... ,, ,, , , ,, ,, , ., , COSTS PREVIOUS DAILY CUMULATIVE IRig ..... $..8,760 $5,062 $13,822 Supervision $4,500 $750 $5,250 Rentals $400 $200 $600 Rou s;?bouts $1,200 $0 $1,2001 , , Transportation $650 $0 $6501 Cement, Acid,.. Frac. $0 $0 Perforating, Logging '" $0 $0' Subsurface Pumps $0 Rods, Scra'pers ' . . $0' T. ubin9, Subs,, SN ...... $0 'FAC, Packer, Re. Pair $0 Others $0 L'~)cation $750 '$0 $750 ,,, Misc. $0 . Electrical $0 Water $560 $560 .. , $657 $657 ~conti~genc¥ "' TOTAL $7,229 $2"~,'489 , , OCEAN ENERGY RESOURCES, INC. DALLY RIG REPORT Well: PIONEER UNIT #1702-15DA Perfs: Location: SEC 15 T17N R2W TD/PBTD: Date: 917199 KB/GL Work Done on: 9/6/99 Others: Present Operation: DRILLING OUT STAGE TOOL N/A 1822' 276'~265' Operations Planned: PREP TO RUN CBL Time From To DAILY OPERATIONS .. -- . , 9/03 - 9/06 '" MIRU CH&P DRILLING RIG 19 W/RELA'TED EQUIPMENT. NU BOP. RECEIVED 140 JTS 2 7/8 J-55 EUE TBG.' ..... . , PU 6 1/4" BIT, BIT SUB, 2 4 3/4" DC'S XO AND 57 JTS TBG. - TAG CEMENT FILL AT 1802~. ..... DRILL OUT CEMENT TO DY TOOL AT 1822'. -' CIRCULATE HOLE CLEAN. ISWlFN. ,,, , ........ .. , . , , , , , ,, .,, ., , ........ , , .., , ,, 3OSTS PREVIOUS DALLY CUMULATIVE ~i~I ' ........... '$8,760 $8,7601 ~uperviSion . $4,500 $4,5001 ~entals $400 $400 ,,,, ,, , ,, ~oustabouts $1,200 $1,200 _r'ransportation ...... $650 $650 .;ement, Acid, Frac. $0 $0 ~erforating, Lo~ging " $0 $0 ~ubsUrface Pumps $0 ~,ods, Scrapers .. $0 "ubing, Subs, SN $0 'AC, Packer, .R. epair ...... $0 :)them $0 .ocation .... $750 $750 /lisc. $0 ..... ,, ,, , :lectrical $0 Yater $0 .... $0 ;ontingency ........ $1,626 .$1 ,.626 ....... TOTAL $17,8861 . $17,..886 ,, Daily Completion Report Well: Pioneer 170215DA Pioneer Unit #1702-15DA Report No: 29 Ocean Energy 06:00 am 06-Sep-99 Operator: Ocean Energy MD: 4265 TVD: 4265 PBTD: PBTVD: Prev. Depth n/a Hole Made Drill Hrs: 0.0 Avg. ROP: Last BOP Test: 15-Aug-99 Field: Pioneer Unit Drilling Days: Completion Days: AFE No: DwIg01D Rig Name: CHP Energy Days On Loc: AFE No: DWI901C Authorized Amt: $328,220 Authorized Amt: $416,553 Auth MD: 4100 Daily Well Costs: Daily Well Costs: $17,886 Auth TVD: 4100 Cum AFE Costs: $422,038 Cum AFE Costs: $158,347 RKB to GL: 276.00 Daily Mud Costs: Daily Fluid Costs: RKB to ML: Total Mud Costs: $18,558 Total Fluid Costs: $600 RKB to Csg Head: 10.33 Cum Well Costs: $580,385 RKB to Tbg Head: 8.58 Wear Bushing In: [] Ground Elev: 265.00 Current Ops: 9/3 - 9/6/99: Drilling out stage tool. MIRU CH&P drilling rig #19 w/related equipment. NU BOP. Received 140 jts 2-7/8" J-55 EUE tbg. PU 6-1/2" bit, bit sub, two 4-3/4" DC's XO & 57 jts tbg. Tag cement fill @ 1802'. Drill out cement to DV tool @ 1822. Circulate hole clean. SWIFN. Planned Ops: Prepare to run CBL Wellsite Supervisors: Dennis Ackerman Mud Engineer: Personnel: Oper: 0 Cont: 0 Svc: 0 Other: 0 Total: 0 Toolpusher: Mike McNaughton TUBULAR INFORMATION Type Size TopMD Btm MD Top TVD Btm TVD FULL 9.625 11 675 11 675 FULL 7 0 4255 0 4255 Casing, Next: Liner, Next: LOT 11.5 FLUIDS AND FILTRATION INFORMATION No Fluids and Filtration Records for this report. No Fluid Loss Pills Records for this report. FLUID LOSS PILLS PACKER DATA No Packer Records for this report. PERFORATION DATA No Perforation Records for this report. OPERATIONS SUMMARY Non- From To Elapsed Code Prod Operations Description No Operations Details for this report. Daily Completion Report Well: Pioneer 170215DA Pioneer Unit #1702-15DA Report No: 29 Ocean Energy 06:00 am 06-Sep-99 No BHA/Workstring Details for this report. WORKSTRING INFORMATION No Safety Information for this report. SAFETY LOGISTICS No Logistics Information for this report. BOAT, TUG & BARGE STATUS No Boat Status Details for this report. No Rig Information for this report. No Weather Information for this report. RIG/WEATHER INFORMATION No comments for this report. COMMENTS Daily Completion Report Well: Pioneer 170215DA Pioneer Unit #1702-15DA Report No: 30 Ocean Energy 06:00 am 07-Sep-99 Operator: Ocean Energy MD: 4265 TVD: 4265 PBTD: PBTVD: Prev. Depth n/a Hole Made Drill Hfs: 0.0 Avg. ROP: Last BOP Test: 15-Aug-99 Field: Pioneer Unit Drilling Days: Completion Days: 1 AFE No: DwIg01D Authorized Amt: $328,220 Daily Well Costs: Cum AFE Costs: $422,038 Daily Mud Costs: Total Mud Costs: $18,558 Wear Bushing In: [] Rig Name: CHP Energy Days On Loc: AFE No: DwIg01c Authorized Amt: $416,553 Daily Well Costs: Cum AFE Costs: $158,347 Daily Fluid Costs: Total Fluid Costs: $600 Cum Well Costs: $580,385 Auth MD: 4100 Auth TVD: 4100 RKB to GL: 276.00 RKB to ML: RKB to Csg Head: 10.33 RKB to Tbg Head: 8.58 Ground Elev: 265.00 Current Ops: Run CBL Planned Ops: Prepare to perforate Wellsite Supervisors: Dennis Ackerman Mud Engineer: Personnel: Oper: 0 Cont: 0 Svc: 0 Other: 0 Total: 0 Toolpusher: Mike McNaughton TUBULAR INFORMATION Type Size TopMD Btm MD Top TVD FULL 9.625 11 675 11 FULL 7 0 4255 0 Casing, Next: Liner, Next: Btm TVD 675 4255 LOT 11.5 FLUIDS AND FILTRATION INFORMATION No Fluids and Filtration Records for this report. No Fluid Loss Pills Records for this report. PAC KE R DATA No Packer Records for this report. Non- FLUID LOSS PILLS PERFORATION DATA No Perforation Records for this report. OPERATIONS SUMMARY From To Elapsed Code Prod Operations Description No Operations Details for this report. Daily Completion Report Well: Pioneer 170215DA Pioneer Unit #1702-15DA Report No: 30 Ocean Energy 06:00 am 07-Sep-99 No BHA/Workstring Details for this report. WORKSTRING INFORMATION No Safety Information for this report. SAFETY LOGISTICS No Logistics Information for this report. BOAT, TUG & BARGE STATUS No Boat Status Details for this report. No Rig Information for this report. No Weather Information for this report. RIG/WEATHER INFORMATION No comments for this report. COMMENTS To: Bret Jameson bret.jameson~oceanenergy.com From: Noel Waechter Wellsite Geologist Morning Report: 8/17/99 Well: Ocean Energy Pioneer Unit # 1702-15DA Surface Location: NE SE Section 15, T17N, R2W, Matanuska-Susitna Borough, Alaska G___L_L: 265' KB: 276' Midmght Depth: 3329' Yesterday's Depth: 3184' Drilled in 24 hours: 145' Today's Activity: Resumed drilling at 15:30 hrs after bit trip and BOP pressure test. Rocky Mountain Geoengineering mudloggers installed a new electronic data recorder (E.D.R.) to replace the one that burned out due to power problems. To date we have encountered total of 37 coals (1 ft or greater in thickness). We have taken a total of 10 coal cuttings desorption samples. We penetrated one more coal in the past 24 hours and collected the cuttings from this coal for desorption (Desorption Sample #99-26). Dan Seamount of Unocal dropped off some composite logs from the Pittrnan and the Big Lake wells that show all the wireline log curves, total gas, and lithology. After reviewing these logs, I still like my original pick for the top of the Tyonek "C" coal at 2660'. Background gas started picking up some around 3200', increasing from 5-20 units to 20-40 units W are currently at 3459' at 5:00 am. The rotary table broke, and we are going to trip out and replace the rotary table when a new one arrives. Mud Gas: Background Coal Gas Peaks 20-40 units 236 units Comments: Drilling with a mud wt of 9.1 and vis of 34. *SEE ATTACHED COAL SUMMARY Daily Report Well ID: Pioneer 1702t$DA Report No: 18 Opeeator: Ocean Energy AFE Nos: DWIg01D. $328,220 Rig Name: CliP Energy Spud Date: 29-Jul-99 Days: Since Spud: 17 On Location: 18 Measured Depth: 3459 Previous Report Depth: 332~ Drill Hfs: 4,0 Last casing: 9,625 at 67.5 Next: Personnel: Operator: 2 Contraotor: 11 Ocean Energy Well Name: Pioneer Unit #1702-150A Report for 24:00 hfs 17-Aug.g9 Field: Pioneer Unit Total Well Costs: Total DaVy Costs; $38,078 MUCl Costs: $721 Total: $18,4C~ Total Vertical Depth: 3459 Hole Made: 130 Average ReP: 7.000 at 4100 Last BOP Test 15-Aug-99 Service; 8 Other: 0 Total: 21 Current Operations; :~ 0400 ju-~t .finishing installing rot table Plannacl Operations: :ih elf hole clean, pump hi ivs sweep, set pipe on bttm and level rig over helle. Toolpusher. Mike McNaughton Well, ire Supervisors: Dennis A~kerman Operations Summary From To Elapsed Code Operations Description Non,Prod 0:00 4:00 4.00 DRILL 3329 - 3~69 130 It, 32.5 fph 4:00 0:00 20.00 REPR rotary table Ioe~cl up, 2 hrs~ Id mt head aha investig;te, fourKI not mt head but table. 2 ha- inve~gate label and mix & pump hi-vis pill and spot on 0ttm. 1 hr pooh to 2400.3hrs pull drive pininn for relay table. § hr pooh (ehairl out). I hr pull and lay out rotary table. 6 hr cleart, tear down & repair rotary table, most of bolts that hold top INate on were broken or missing. Repalce and tighten bolts. Put table ba~ together, Comments it appears that wtih the heavy side load (msialigned over hole) that wtlh the top plate being able to move that that was the problem. The ring gear was able to move up and dawn 1-2 inches causing the clanging & banging. Repaleed and tightened the 10oils and all appears OK. Can move the table frseiy by hand and can feel er hear nothing wrong. Mua man cleaned mud tanks ~hile working on mt table. Loc work on t702-15 DD Is progressing nicely. Have meat of main pad area done but still working on covering rest of pad with 6 inches of gravel. Am buying gravel from Joke. $titl have boo koo (lots) water around and on pad. Density Vis Fill Cake PV YP 17-Aug 23:30 at Depth ~459 9.~0 37 8 1 § 8 Item Description gel- 100# bag engineer- I man From To 3329 3459 ROP Avg Max ~2.5 70,0 Mud Information , % Gels Temp pH Solids Water Oil Sand Chloride 10e t0m 30m In Out g 3.1 95 O 0 1400 4 10 16 90.0 68.0 Mucl Consumable Items Qty. Cost Item Description Qty. Cost 7 89 Gelex- 2~ bag 2 82 I 600 Drilling Parameters WeB RPM Torque Flow Avg Max Avg Max Avg Max Avg Max PSI 30 70 340 950 page 1 Daily Report Well ID: Pioneer t70215DA Report No: 18 Ocean Energy Well Name; Pioneer Unit gI702-15DA Report for 24:00 hm 17.Aug-99 Miscellaneous Drilling Parametem Hook Loads (lbs): Off Bottom Rotate: Pick Up: Slow Ciroulation Data: Pump I: 29 spin ~75 psi spin psi Sla(~k Off:. f~ Wear Bushing Installed opm psi Rotate Hrs Trip Hrs Casing: 118.5 15 0 iii · Hole No Run Make Model Diem Made 4 1 HCC CT.e9 8.750 275 Depth From To Avg 3329 34.59 19 Bit Informafion~ FLO.P. W.O.B. R,P,M, Torque Mud Pump Avg Max Avg Max AvgMax Avg Wt Flow Press ;1.5 28.9 70.0 30 70 9,50 ;350 950 . Mud Log Information Max at Depth 236 3408 Gsa Drilling Per; Connec~t, Trip Exp, Pres Hr~ RKB Elevation: 276 ft Uthelegy: out 10 ft ooal 3405-3zt18. Best ~al yet, Rig Information Rig Name: CHI= Energy Equipment Problems: rotan/table Iool<ed up, pooh to repairl/repalce , Solids Control Irlformatlon. Screen Size.: Top Middle Bottem Equipment Ueegle: ShaRer No 1: 80 80 80 Desander: Shaker No 2: 110 t10 Desiltar. Shaker No 3: Degasser. Shaker No 4: Centrlf. ge N= I: Centrifuge No 2: .... I. oglsti~ Infom~ati=n 12 Solids Removal Bulk Materials Consumption and Inventory: Used This Received This Report Period Report Period Inventory Barite: o 0 o Gob; 0 0 0 Cement; 0 o 0 Fuel: 0 0 0 Freeh Water. 0 0 0 Drill Watsr: 0 0 o Truok/Boat Solids Removal ._ ~ Drill Pips At LoCation: DP Size Joints Weight Grade l'hread 4.5 150 15,6 E 4,SEH P~e2 Well c~m: 6?4cijao? II ' -' I limit . _.!_~._~ _ _1 II ..... .... II ~ I ..... i ._. '- ii TuGU~K FULL ~,~6 ~ ~ ~5 t 1 I~:" ' ' ' '~""" ........ W~T=,~= H ~ ~=~-~ ........... ~ ~ ~ ~ YP ~ Mi ~ ~ ~ ~ ~iWMM ~l~ MIT ~IT ~ e,~ le le ~ B/la U 0 I ~ 6 ~ 0 D ~? ...... iiii i1__ Illl . -- ~ ~ a.m HOc ~T~ qM~ Cl~X mil ........ I I '" nmm~e PAlMErS (A~M~) millime I m III _ III lei I I I ...... HYD~U~ ,INFORM~ON " ..... bU~Y~ ..... '" ~-~ iiii ii I~ i I ...... it ii i Ii1_ ~ _ ~ ~ ...... OPE~TIO~~MMMY I i II . r J .-- Chit CA Flew I)1~1 Fell; TO Ocean Energy Well Name: Pioneer Unit ~702-'ISDA Report for 24;00 hfs 22.Aug-95 Operator: Ocean Energy AFE Nos: DWI@01D - $32B,2,20 Rig Name: CHP Energy Spud Date; 2e-,Jut-99 Days: Since Spud: 2.2 On Location: 23 Measured Depth: 426S Previous Rapo~: Depth; 3943 Drill Hm: 17.0 Field: Pioneer Unit Total Well Costs: $724,77~2 Total Daily Costs: $18,71{5 Mud Costs; $970 Total: $23,307 Total Vertical Depth: 39434260 Hole h'=3 de; 322 Average ROP: 18.9 Last Casing= Personnel: Operator:. Current Operations: Planned Operations: Toolpt.~her: Wetlsit~ Supervisors; 9.625 at 675, Tested te 11.50 Next; 7.0130 at 4100 2 Contractor: 11 Service: 8 Other: spot hi -vis pill prior to pooh '.'or logging logging, tih, cir hole cJean spot bi-vis pill, ~3ooh sideways, run Mike McNaughten Dennis Ab-'kerman Operations S~mmary .... From To Elapsed Code 0:00 11:3:3 tl.50 DRILL 11:30 12:00 0,50 ~ERV 12:00 17:3(3 5.50 DR!LL 17:30 15;30 1,00 CI~C 18:30 2.3:30 5.00 TQH 23:30 0:00 O;,5~ TIH Last BOP Test: · 15-Aug-§9 Total: 21 Operations Desoriptiort 3943 - 4158, 215 it 18.89 fph lube & sewi=e dg 4158 - 4265 107 t~, I=..45 f131~ TD ~ 42{i5 ~ir bttm. pooh ~o DC, SI.M, rite st3ot .~414..3;385, 2,.5 k Ol3, work a couple times then OK, Trig leek long because af eLM and trouble witl~ ~ripptng c~utc~, see commonS. SIM 9.64 ti long, no m~rection tih Comments had to work pipe a couple times (~ 3414-3385, ?.,5 K cp, with fig tripping clutch slipping it was hard to really see how much we would of had to pull, But was able to work Iflru it and catty on, Having ~olids cePtroi do de-watering when finished drilling sad while logging. SLM. g.a4 ft long. no ¢orreatJon, Spoke w/John Spaulding of AOGCC and was waived for weel¢!y bop test because 'r13 and no well control problems, No fill & no problems goirlg baokto i;ttm f,=r short trip. HAD 41 PPM 1-12S ON BTTIVI$ UP ON SHO~T TI~P, ALARM AT ~SHAKER WENT OFF l:enelty Vis FiR Cake PV YP 22-Aug 18:45 at Depth 4265 9.30 52 4.8 I 17 18 Item Des~ription gel- 100~ bag engineer, 1 man From To 3943 4265 ROP Avg Max 18.~ 70,0 Mud Information % Gels Tamp pH Solids Water Oil,.qand Chloride 10s IBm 30m in Out g 5.2 g4,8 0 0 gOO 5 11 16 82.0 8a.~ Mud Cor~umattle items Qty. Cost Item Des=rlption Qty. Cost 18 204 Paly Plus RD - 5[~ I~ag 1 143 1 600 Oeiiling Parametem RPM Torque Avg Max Avg Max 75 80 WOB Flow Avg Max A'~g Max PSi :~0 33 350 3~5 1100 page~ Daily Report Well ID: Pioneer1702'lSDA Report No; 23 Ocean Energy Well Name: Pioneer Unit Report for 24:00 hfs 22-Aug-99 Miscellaneous Drilling Parameters Heel< Loads (lbs}: Qff Bottom Rotan: 92 Pick Up: Slow Circula~Jon Data: Pump 1: 28 spin 325 ps~ spin I~i Hole No Run Mal(e Model Diem Made 4 1 HCC GT-09 B.75C I0~t Depth From To 100 Slack Off: 90 i.~ Wear laushin.q Installed spin psi Rotate Hrs Trip Hr~ Casing: 156.5 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 49.5 21.8 70.0 30 32 75 80 9.40 350 1100 ~ud Log Information Gas Gas Drilling Pore Avg Max at Depth Connect. Trip Exp, Pres 7 ~ 58 3460 16 Li~hology: 81~% ss, 10% s[lst, 10% Goal, found a coal 4134-38, 4140-a,1,~2. 414R--~0. this was ~l'm coal the geologists was looking for. -- Rig Information Rig Name: CHP Energy RKB Elevation; 276 fi Equipment Problems: Irl~ping ctutclq not wo~ing up to full potential, at about 116-120 K, it slips especially on the tY, ird wrap on the drum, Had to lay down 5 its dp so dido:: u~e thirct layer on d~um. Then pooh without too mu~ I~roblerns. LecatiOll Condition dry Solids Control Infemlation Semen Size: Top Middle Bottom Equipment Usage: Hrs. 8baker No 1: 80 80 80 Ig~ancler; 24 Shaker Ne 2: 110 1 I0 Deallter: ShaRer No 3: Dage~er: Shaker No 4: Centrifuge No 1: 24' Solids Removed Cen~fuge No 2: ~oJids Removal Logistics Information.. Bui~ Ma:oriole Consumption and Inventory: Used This Received This Report Period Report Period Inventory Barite: O 0 0 Gels: 3 O 0 Cement: o 0 0 Fuel: 0 0 '0 Fmstl Water; 0 0 0 Drf!! Water: 0 0 0 TrueJ~BOat Status: Drift Pipe At Loeationt DP 8i~e Joints Weight Grade Thread 4.5 '150 16.6 E ,I..5EH Page 2 Daily Report Well ID: Pioneer~70215DA Report No: 23 Ocean Energy Well Name: Pioneer Unit #t702-t 5DA Report for 24:00 hrs 22.Aug-99 First Aid: 0 Medical: Accident Descril:4ion: Meetings/Drills Time Descl~ption : ' BOPTest 8ky Condition: pc Air Temperature: 60,0 deg F Wind Speed/Dir, 0 / Safety Information Lgsr Time Accidents: 0 Days Since LTA; 23 !~ Crownamati¢ Che~k Weather Visibility: Bar, Pressure: Winct Gusts; P,,lntect: 6:4123.Au~,.~9 rage Daily Report Well ID: Pioneer 170215DA IR~port No: 2;2 Ocean Energy Well Name: Pioneer Unit #1702-15DA Report for 24:00 hrs 2t-Aug-99 Operator: Or~aq Energy AF~_ Nos: DWlg0q D - 5328,2:;[0 Rig Name: CNP Energy Spud I~1~= 29-Jul-99 Days: Since Spud: 21 On L~ation: ~aure~ Dep~: Previous Repo~ ~pth: 3459 Drill Hfs: 23,0 Field: To,al Well Coe~s: To,al Dally Costs: Mud Costs: $1.':19 Total Vertical Depth: Hole I~ade: Average RQP: Tmah Pioneer unit $706.007 $18,704- ~2,337 3943 4~ 21,9 Last Caring: 9.625 at 875 Pemonnei: Operator: Current OperaUons: Planned Operations: Toolpusher: Wellsite Supervisors: Next: 7.000 at 4100 Last BCP Test.' 15-Aug-99 Contractor= 1~ Service: 8 O~er: 0 Total: ddg ahead ~ 40~d ~ 0~ HRS ahead to TD, g~logist says will probably wa2t to drill an e~m 150 or so Mike McNaughton Dennis Ackerman Operettas Summary From To Elapseci Code Operatiene Description 0:00 9:00 9.00 DRILL 3459 - 3658 197 ft, 21.38 fpn cJ:O0 9:30 0.50 SERV lube & service rig 9:30 !5;00 5.50 DRILL 38§6.3783 127 ft, 23 fph 15;00 15:30 0.§0 SURV widJne survey ~ 3751 - 1 de§ 16:30 0:130 8.$0 ~RIL,- 3783 - 3943 160 fi, 18.a fph Comments all going smooth last 24 hrs, will have yp to 18 by 'ID. Geologists say will probably c[rtll an extra 150 as expect large coat section al~out 4100 Mud Information % Gels Tamp Solids Water Oil Sand ChloHde 10s 1Om 313m In Out 5.4 94.6 0 0 1400 5 7 13 76.0 88,0 Mud Consumable Iteme Density Vis Flit CaRe PV YP pH 21-Aug 20:30 at Depth :395t 9.313 $1 6.6 1 18 18 9 Item Description engineer- ! mar~ Poly PT~ RD - 50~ bag From To 3459 3943 Slow Cimulation Data: Pump 1.' 30 spin ROP Ava 2~,0 65.0 Off B(~tt~m Rotate: Qty. Cost Item Description 1 600 gel. lOO~ bag 2 DHIling Paramstem .., ~ RPM A~ ~ Avg M~ 3~ 34 75 Miscellaneous Drilling Parametem 93 Pi~k Up: 300 psi spin psi Qty. Coat 2D 255 Torque Flow Avg Max _Avg Max PS1 355 ~ 060 97 Slack Off; 85 L~ Wear Buslfing Installed spin Rotate Hm Trip Hfs Ca~ing: 139..~ 20.0 Page Daily Report Well ID; Pioneer tT02'fSDA Report No: 22 Ocean Energy Well Name: Pioneer Unit ~702-t;;DA Reloort for 24:013 hfs 21-Aug,99 Bit Information, Hole R.O,P, W,O.B. R,P,M, Torque Mud Pump No RLInMake Moclel Diem Made Hrs Avg Maz Avg Max Avg Max Avg Wt Flow Press HCC GT.0B 8,750 759 32.5 23,4 65.0 30 33 75 80 9,20 365 1060 Mucl Log Informal~on Delath Gas Gas Drilling Pore From To Avg MaX at Depth Connect. Trip Exp. Pree 3459 3a, L_~ 14 143 3816 28 64 ~thology.' 70% SS, 20% al[sat, 10% ;oal, drilled through 10 smail coals, biggest one 3602-3612 geology s~ys samples good Rig Information Rig Name: CHP E~ergy RKEi Elevation; 278 ft Equipment Problems: all running smc~ethly far last 24 I~rs. Location Condition goocl Top Middle Bottom 8o al:) 8(] 110 110 Screen Sizes= Shaker No l: Shaker No 2: Shaker No 3.' Shaker No 4: 8olrd~ Control Informffdon Equipment Usage: Hrs. DeaanCer:. 24 Deailter: Dega~er: Centrifuge No 1: Centrifuge No 2: Logistics Information ., . 24 Solids Removal Solids Removal Bulk Materiala OonsumpfJon and Inventory: Usect This Rec~ivecl Thl~ Report Period Report Parred Inventory Barite: O 0 0 Gels: 0 0 0 Cement: 0 0 0' Fuel: 0 0 0 Fresh Water, 0 O 0 Drill Water: 0 Q 0 Truck/Boat ~tatUs; Drill Pll~e At Location: DP Size Joints Weight 4.5 150 18.6 First Aid; 0 Medical: Accident Description: Meetings/Drills Time Oeaorlpflon ~ BOP T~st Sky Condition: cloudy Air Temperature: 55.0 dog F Wind Speed/Dir: 51 NE Grade Thread E 4.SEH Safety Information Lost Time Ac=idents: Days since LTA: '~ Cmwnametic Check Weather ,, Visibility: Bar. Prea,~ure: wind Gusts: ~age 2 Daily Report Well iD: Pioneer 1702'JSDA Report No: 22 Ocean Energy Well Name: Pioneer Unit gl 702-I 5DA Report for 24:00 hrs 21.Aug.99 5'34 22.AUg-.qg Page 3 Daily Report Well ID: Pioneer 17D21.~DA Repo~ No: 21 Ocean Energy Well Name: Pioneer Unit #1702-I$DA Repo~t for 24:00 hm 20-Aug.99 Toolpus her. Wellsite Supervisors; Opera. r: Or. eon Energy AFE Nos: DWI9D1D - $,328,220 Rig Name: CHP Energy Spud Date: Z~-Jul-99 Days: Since Spud: 20 On Location: 21 Measured Depth: 3429 Previous Report Depth; 3459 Drill Hfs: 0 Last Casing: 9,625 at 675 Next~ Personnel: Operator= 2 Contmotor: 11 Currant O=erations: ddg ahead ~ 3532 Planned Operations: drlg ahead te td, p~ly piu$ concentration is .5 01313 Mike McNaugh~en Dennis A~er~an operat[or~ Summary From To Elapsed Code 0:00 8:00 8,00 REaR 8:00 13;00 5,00 RE,~R 13:00 1.~:00 2.~0 REmR 15;00 19;[30 4,00 REPR 19:00 21:30 2.~0 REPR 21 ;30 2:3;00 1.80 REPR 23;00 O:00 1.00 REPR · ,- i Illl III ----- a,alal Field: Pioneer Unit Total Well Costs: ~87,303 Total Daily C~: $9,145 Mud Costs: $600 Total: $21,218 Total VeAical Depth: 3459 Hole Made; Average ReP: 7.0(~0 at ~100 Last BOP Test: 15-Aug-99 Service: 8 Other: 0 Total: 21 Operations Das=dption wait an swivel n~ swivel ~na kelly tth (cir 13u ~1500 fi), t~ 2680 brae slips,, hit w/elevators, wait on replacamar~t slips work on and adjust brakes tih ~o 3425, w/o problems, Install mt head wash 3425.346D, 10 fi fill, cbu Comments I~s~ 3 hrs due to not having parts or replacemem dp slips, I~ringmg yp and vis up helped gmaUy, only 1(3 ftfill on Mtm after ~. ~/'2 deys. No plugge~ no~.Jes. ............. Mud Information ......... % pH Solids Water Oil Sand Chloride Non. Prod X × × Gels Temp ~Om 30m In out Density Vis FiR Cake PV YP 20-Aug 23:30 at Depth 3461 9.20 51 7.8 1 10 13 9 5.2 94.8 0 O 1400 Mud Consumable Items 4 7 12 78.0 85.0 Item Description CRy. Coat Item Des=dption engineer- 1 man ! 600 Mlscellaneou-e DHIling Parameters Hook Loads (lbs): Off Bottom Rotate: Pick Up: Slow Circulation Data: Pump 1: 31 spin 270 psi spin psi Cost Slack Off;. Wear Bu~hing Installed opm psi I~tat~ Hrs Trip Hrs Casing: 118.5 2D.O Page 1 Daily Report Well ID: Pioneer 170215DA Report No: 2q Ocean Energy Well Name: Pioneer Unit ~1702-1 {;DA Report for 24:00 hfs 20-Aug-ga i'4o Run Mal(e Model Diem ~, 1 HCC GT-0g $.7.~0 Hole Made Depth Prom To 3460 346O I.ithelo.qy: So,eon Sizes: Top Middle Shal~er No 4: 80 80 Shaker No 2: 110 110 Shaker No 3: Shaker No 4: Avg Hrg Bit information - R.O.P. W.O,B. R,P.M. Torque Mud Pump Av9 Max Avl] Max Avg Max Ay9 Wt Flow Press Mud l. og Information Gas Gas Drilling [=om Max at Depth Connect, Trip Exp. Pres 64 Solids Control Information Bottom Equipment Usage: 80 Desande~t Desilter: Degaaeer: centrifuge No Centrifuge No Logistics Information Bulk Mate~als ConaumPtion end Inventory: Used This Received This Report Period Report Peflod Inven[ory Barfte: 0 ,0 0 Gels: 0 0 0 Cement; 0 0 0 Fuel: 0 0 0 Fresh Water: O 0 0 Drill Wamr: 0 0 0 Truck/Beat Status: Hrs. Solids Removal Solids Removal Drill Pipe At Location: DP Size Joints Well]hr 4.5 150 16.6 First Aid: 0 Medical: 0 A;oident Desoflptlon: Meetings/Drills Time Description [] BOP Test Sky Condition: ctoudy Air Temperature: 55.0 dog F Wind SpeedlDir: 0 / Grade Thread E 4.6EH Safety Information Lout Time Ac=idents: 0 Days 8incs LTA: 0 [] Crownamatic Check Visibility; Bar. Pressure: Wind Gusts; 15 12:35 21.Aug. g9 Page A~UG, 19, 19991 7: ~6RN~ ( '-'" -- ' .......... -' -- ......... Pi ,~naer Un, ittHTO2--lSOA Rel~rt No: 19 24:00 Rlkl; P~a' Unit Rig Nmn~ Days On I.~: tg AF~ NO,' DWLa31D TooI~. Ml~e I~Nsugl-~n C)Umr:. 0 Tatah 21 . .. I_1 I I - '--' ! I.. __~'- _J I II TUBULAR INFORMATION mmMn T~TVD Btm TVD I el IIII ..... ...... -- __ I~ItU BIT INFORMATION See 1¢e ~ 440 240 ,. - .... TW=,. SL~e TopMo FULL cj.625 :L 2 ~, Next; 7. ~ 41ca IuD, 4,C0 T'vD outM Omth hens PV YP V~s lan' ~ g~ tn ~3 47 4 1 8.~ HC~ GT~ RPM Flew P'GI IIK)P WOB No Sk,~ Pum~ naa ~thl~ mpan ..... I1_ I Il -.- Ne Survey Readtn~ far th|l report. ,m -'-._lin I __ .. -- ] _ SLOW IN. IMP DATA ........ . I I -- :1_ __. I I · Il -. SURVEYS 12'.~ I~D 1 ~ REPR x 13'.~ I~DD 0.~ REPR x 14~0 16,,~ 2,oD REaR x I;,:33 Z1.t:C 1,.5D RI~R x :~l:0o 2:~:~ t.~O tart. pR x 22:33 O:OO ':J~ REPR x ..... J____. II. __' ...... . ....... _ · _ Well: Pioneer 170215DA _llJ ...... J( . ' ..' ' " Pionaer Unit MUD LOG ' (' " Ocean Energy Max C. Mm T?.p ~~ ~ ROTA'nN~ I,IRS: Since Inspe~ion: Loot &~k~Mtt dm's: ___ill LOOIGTIG8 Barite 0 0 0 Ual. 0 0 0 C, Mtmmm 0 0 0 Omi Blead 0 0 0 Fuel 0 0 0 ~ah W~r 0 o 0 Odll Wt~ 0 0 0 '- ' I-- ' . .. I Ill ..... mi Ill/._. GOAT, Tile i BARGE STAYU$ Rki Mime: Clip ~ 4.~iEH _. I Daily Report Well ID: Pioneer 1702t5DA Report No: 20 Ocean Energy Well Name: Pioneer Unit ~702-15DA Report for24:00 h~s 19.Aug.g9 Operator'. Ocean Energy AFE Nos: DwIg01D - $328,22D Rig Name: CHP Energy Spud Date: 29-Jul.99 Days: Since Spud: 19 On LoGation: 20 Measured Depth: 3459 Previous R~port Depth: 3459 Drill Hra: Field; Pioneer Unit Total Well Costs: ~78,158 T~tal Dally Costs: $9,145 I~d Co, ts: $600 Total: $20.~ 8 Total Vertical Depth: Hole Made: Average EDP: Last Casing: Personnel; Operator: currant Operations: Planned Operations: Toolpuaher. Wellsite Supervlsom: 9.625 at 675 From To Elapsed Code O:00 0:00 24.00 REPR Next: 7,000 at 4100 2 Contractor: 11 Service: 8 wait on swivel, par~ arrived late p.m. This =late. in~tall swivel & kelly, tih, cant drlg al~ead Mike McNaughton D~nni; Ar, kerman .... Operaaorm $~wnmary Operations Oesr, ription wait on parts for swivel, .. Mud Infoemetion % YP pH Solids Water Oil Sand Density V'm Flit Cake PV 19-Aug 18:00 at Depth 3459 9 §.4 94,,8 0 0 ,, Mud consumable Items Cost Item Descflptlon 1 6OO 34~9 14 Item Deaoripfion City. engineer- 1 man Rig Name: ClIP Energy Equipment PrOl:Nems: repairing swivel. LocaUon Condition good, mostly dry Semen Sizes; 8baker No I; Shaker No 2: Shaker No Shal(er No 4: Top Middle 80 80 110 110 Sk7 Condition; Air Temperature: Wind 8peed/Dir: ~5,0 dog F 0t Chloride Last BOP Test: 16-Aug-99 Other: 0 Total; 21 10s lorn 30m Non.Prod X Tamp In Out 1400 5 ~2 15 68.0 90.0 Rig Information RKB Elevation: ... 276 ft 8olids Removal Solids Removal Solids Control InformaUon Bottom Equipment Usage: 80 Desander. Centrifuge No 4: Centrifuge No 2:. Weatller Visibility: Bar. Pmuure: Wind Gusts: Prlnr~l: $:2g 20-Aug-g9 Page 1 WMi: Plmmer 17D~:lBI2A ii ~ __. ., · MUD ~' I~CIMM E. NTiI I ill Daily Repo Well ID: Picneer 170~.15DA Report Not 25 Ocean Energy Weii Name: Pioneer Unit #1702-15DA Report for :24:00 hm 24-Aug-99 O~mtor: O6ean Energy AFE NOs: Dwig01D - $32~,222 Rig Name; CHP Energy 8pud Dace: 29-Jul-9~ Days: ~ince Spud: 24 On Lacation: ~5 M~asured De~: 4265 ~revioua Re~o~ Depth: ~65 9.82.~ at ~?5, Tamed to ! I.B0 Next: 1 Co~tt~ctor: 11 From To Elapeecl Fie~cl: Pioneer Unit Total Well Casts: $770,062 Tote; Dai!y Cost~: $25,65§ MU¢ Co-~m: $20Q Total: $2.4,107 Total Vertical Depth: ~2.55 Mole Made: Average ROP: 7.000 a[ ~.I00 Last BOP Test: 15-Aug-gCJ Service: .~ Other; 0 T~tal: 17 finish lagging, ,'ih. ba dp. run csg. om! same Mike McNaugntan ~e~nis A¢~erm~n Oper'~ons Summa~ C~de Operations Oes~ripUon 0:00 2:00 .o,g0 WLOG run#3 cont. RamstMty tool failed, working on tools 2:00 8:00 6,~0 '~OG run ~, clip.tar, 423T c om men ts Mud lnfQrmation % YP pH Sotids Water Oil Sand Tamp Chloride t0s 10m 30m In Out 900 11 IB 19 S0.0 88.0 Density Vis Filt Cake PV 24-Aug 23;00 at ge~th 4285 9,20 ~'1 4.8 I :20 23 9 52. 94.B 0 0 Mud Consumable Items Qty, Co~t l~ Description 9 115 engineer- 1 man Safeg, Information ...... L~st Time Accidents: 0 C~ty, C~t ~ 600 _ ,mi, Days ~ir~e LTA: 25 ~ Crownamatic Check t~,'nted; 5, 55 21i-A ~J.99 P~ge 1 W~H ID: '?io~e~r Name: CHP ~pud Dam; 29.J~-99 ~ured ~ep~: Previcu~ Repo~ Depth: DHit Hm: 0 Las[ Ca~ing: ~,~2~ at Next: Pereonnet: Operator: Gun'ant Operafio~a: P!annea Operations: Toolpu~her: Wellsite Supervisors: From To ~_lapsed 0:00 2;00 2,00 Ocean Ccntr.~ ctoc. 11 Ocean Energy We{I Name: Pioneer Unit #~702-15DA Rel3~rt for 24:00 bm 24.Aug.99 F{eld: Pioneer Unit To=i Well Costs: $74~,407 Total Daily C~sts; $0 Mud Coet~: $0 Total: $2390? Tot~.l Vertical Depth,: Hole l;~zde: Average 7.000 at 41O0 L~st BOP Test: !5-Aug-~9 Service: 5 Other:, 0 Total: '17 Mike McNaug~lt~n Oenni.~ Ac~erman Operations Summary Code Operations Description WLOG run#3 cont Resist~vRy tool fail~d, working ~n tools 3.00 WLOG m~, ~, ~ipmeter, ~-237 Comments four geologists ~'eleased un+,ii e?m? su?face on next hoie, AU~.~5.1999 ?: 55AM _. OCERM tdt~_P. GY kc-SoU~L~..b Daily Report We~l ID; Pioneer Report No: 25 ,.g , fi Ocean Energy Well Name: Pioneer Unit ~ 702-~ ~DA R~p~n for 24:~0 hm 2~Aug-99 Opera.r. Ocezn Energy AFIE Nos: owIg0!o- 5328,~D Rig Name: C,~P Ener_u--y Spud Date: 2~aul-@B Days: Since'Spud: Gn L~cation: Measured Oepth; ~ Previous Report Depth: 42.65 Last Casing: Pe~sonne;: Operator: Current Operations: Planned Operations: Toolpushen Wellslte Supervisors: L,m I FeDs To 8:3C ~ 17.?.0 ~ 3;00 13:00 15;30 ;lei{l: Pioneer Url,t Total Well C~sts: $786,371 Total Daily C~.~: $16,309 Mud Coe~: $714 Total; $2~,821 Tarsi Vedical Depth: Hole Made: Avera~e ROP: ~5;$0 2:3:30 23;:30 9,625 at 67B, Tested to 11 ..~0 Next: 7.000 et 41 O0 2 Contractor: 11 Service: -~ Other: 0 runl~i~9 ~nt run 7" ~g, cir an~ ~reak b~ mud, cat w/2 stage ~t j~b Mike McN~ughten Dennis A~ke~sn ~pemtiens Summa~ Elapsed Code Operations ~esctfptlon 4265 0.50 8OPOT 3.80 TIH 1.00 CLN 250 CRCF 8.00 ~'OH 0&0 @OPOT ,. Last 80P Test: 15-AUg-99 Total: 18 ~ull wear bushing washs ~3 bL'a'n 41 BB47.85 - no fill - pte~utlona~ ~r & con,ion mud to ~n ~g, ~irty heavy returns a: s~aKer but deanee up nicz~y at b~ms up, sp~t hi-vis mw~p prior to Id dg pooh sideways, ~ange dp ra~ ~o 7" csg tams Gommen~ Icl d13 took longer tha~ expected :3y 2 hrs. Mud Information ......... % Gels Temp pH SoiidsWaarOll Sand Chloride 10s 10m 3~m In Out 04.8 0 0 900 11 ~O 19 80.0 88.0 Density Vis Flit Cake FV YP 24-Aug 23:00 st Death 4285 ¢=.20 SI 4,8 1 20 23 Rig Information ,. Logistics I~forrnaUon .... .- ,, Name: OMP Bnergy Sulk Materials Consumption and Inventory: Used This Received This Rel~rt Period R~port Period Inventory aarite: 0 0 0 Gels; O 0 0 Cement: 0 0 0 Fuel= 0 0 O Freeh Water: 0 0 0 Drill Water: O O 0 Trucl(/Boat Status: ,m Page I Daily Report Well 113: ]~ien~er 1713~15DA Ral:ort No: 26 Ocean Energy We~! N~rne: Pioneer Unit #1702-15DA Repert for :2.4:00 hfs 24-Aug-99 Rmt Aid: 0 Medical: 0 Ac¢ide.~t Description: Meetin$s!D~lis Time Elescriptien Safety: cunning csg BOP Tess Sky ConaRion; cloudy Air Temperature: 55,0 -~eg F WincJ SpeedlDlr: C 1 Safet7 Information Last T~me AG~iCents: 0 Days Since LTA: 25 .-- i_ Crewnamattc Check Westher Visibility: Bar, Pre:ssure: Wind Gusts: 2O Daily Report Well ID: Pioneer J?02dSDA Report No: 27' Ocean Energy Well Name: Pioneer Ufllt ~702.1SDA Report for 24:00 hfs 25.Au§-99 opeeaton Ooean Energy AFE Nos: D~SO1D- $328,229 Rig Name: ,~HP Energy Spud Dam: 29-Ju1~99 Days: Sin~e Spud: On Looation: Measured Depth: 4265 Previous Report Depth: 4265 Drill Hfs: 0 Field; Pioneer Unit Total Well Costs: $806,953 Total Del .h, Costs:~0,582 Mud Costs: $! ,7§7 Total: $26,578 Last Casing: Pemonnel: Operator. current Operations; Planned Operations: Toolpusher: Wellslte Supervia~m: From To 0:00 0:30 0:30 11 :OD 11:00 15:30 15:.~0 1~:00 t6:00 17:30 ?.000 at 4255 Next: 1 Contractor: 11 getting ready to ~rr~t 2nd stage cmt, ncl, set slips, rd move to 1702-~4CC Mike McNaughton Dennis Ackerman Operations summary Elapsed Code Operations Description 0.50 130POT ~ont install 7" c.~g rams 17;30 19:00 19:00 0:00 Total Ve~fioal I::lepth: 4265 Hole Made: Average ReP: Last BOP Test: 15-Aug-gg Service: ~ Other: 0 Total: 17 ~0.C-O CASE cu&run 103j~s7"23#CF-5OLTCardcsg 4.50 CRCF cir &cond., ctmp yp f/20 to 6, vis 52 to 36, wi: 9.3 to 0.~0 OTHER safety meeting, crating 1.50 CMTa 20 bb~$ mca-4 spacer, 11.5 ppg, 515 sx (99 bbl) "G" atoll5.8 ppg, dispalee wt 168 bbls (102 water, 66 bbls mud), emtta surfaee at 100 bbls into displacement 1.60 CRCF drop bomb, open dv ~ 800 I~ai, ~ir I barn (~ 800 psi, Iot~ of ~labbered mud and cant at surface dght away. 5.~D CRCF ~ir & oondition mud for next stage, Mud Information % Gala Tamp Oer~ity Via Flit Cake PV YP pH aollds Water Oil Sand Chloride los tom eom In Out 2S-Aug 23:45 at Depth 4265 8,90 36 15,8 I 10 iS 9 4.6 95.4 0 0 900 4 7 12 75,0 88.0 ......... U[ d C0n u bla. Items ....... Item Description Qty. Cost Item Description City. Coat Desco CF - 25# bag 4 208 engineer- I man i 600 Borax - 50~ bag 22 9~S2 Safety Information First Alci: 0 Medioah 0 Lost Time Accidental 0 Ao=ident Description: Meetings/Drills Time Description Safety: cra: first & ~econd stage ~ BOP Te~t ~ Crownamafi¢ Cheek Oaya Since LTA: 26 Page I ENERGY RESOL~RC~_5 Daily Report Well ID: Pioneer t?(:12~SDA Report No: 27 Sky Condition: cioudy, rain Air Temperature: 56.0 de; F Wind Speed/DIr: 4 / NE Wmather -- Ocean Energy Well Nnme: Pioneer Unit #t 702-15DA Reportfor 24:00 hfs 25-Aug-S9 , Visibility; Bar, Pressure: W~nd Gusts: 10 PMnted: 6:'17 26.Aug. gS Page 2 Will: Pioneer I?'OIIIIDA P|~nier Unit II il , , I . _ Iml . mm, mm Ave. IK]F: LeMBOI)?sM: 15.A~ WNrBuehlneln: I~ .... I I .... II II · II i i . .i Pb, nned Gpw; rn~l to W~l~ lUlM~leare: DenflJe Adcem'mn Mud r:ngl.4m: ~. II(n. ..... Il__ II I i ILl I F',, LL 9,1525 11 FULl. 7 0 i i ii .i I · ' .... ~ MD Too 67~ 42~5 o 4~B I'--F'~LUIDG d~I~D FIL'TRATIGN INFORMATION No Fluids and Filtration Ilreeeldi for 1Ills fJp~rL I I ql i FLUID LOSS PILl.&' No Fluid ~mm Plllm pAGKEi~ DATA '- Nu Pmskur Mi;erda lin' tklm IripM'L _. · mmTVD 675 4255 4,255 ~ 'lVO: ,41o0 I~ICB W M~ ........... , ......... J ....... " P~F~FO~T~C)N D~TA .... Ne Perlomillm Recerde le~ Ikii vii)H, 11,5 Dally-Completion Report Well; '1 i _ -- II (. I I -- -- i- ~ ' No Lollsttca Inlm'malle. I~' Ibis rillarL Bio RII Idermit/en ~ MIs rlpad, l~: I~ via,: 15 · I~eport No: 21 .i i I i ii i I m 1 . Il III I · I. .l_ II RiGh~fP. ATHER INF"01~ATION ' "' " ~ 3 t NE IAIda; &umfl ~ / i ___~ I ~ ..... II ..... ill GOMMENTS Daily Report Well ID: Pioneer 170215DA Report No: 18 First Aid: 0 Medic:el: Am=i~lerrt Descwlption: riVetings/Drills Time Des=ription ~ BOP Test Sky Condition: clear Air Temperature: 65.0 deg F Wind Speed/Din 3 / SE Safety Information Lost Time Aooident~: Ocean Energy Well Name; Pioneer Unit #1702-15DA Report for 24:00 hrs 1?-Aug.99 _- 0 Days Slr~e I. TA: 18 [~J Cmwnamalis Check Weather Vis~ility: I~r. Pressure: Wind Gusts; 25 ~intecl: 6.'3S fle.Aug, gg Page ROCKY MOUNTAIN GEO-ENGINEERING CORP. 2450 Industrial Blvd. Grand Junction, Colorado 81505 (970)243-3044 MORNING REPORT DATE 8/16/99 COMPANY & WELL OCEAN ENERGY RESOURCES INC. DEPTH TODAY 3329 FT. YESTERDAYS DEPTH FORMATION NOW DRILLING IN ' Tyonek C coal FORMATION TOPS Tyonek C coal ~ 2660 ft. PROJECTED FORMATION TOPS BACKGROUND GAS 10u. Tyonek P coal 3200 ft 3184 FT. FT/24 Hr 145 FT. TRIP GAS 197 AT 3184 GAS PEAK 21 ~ 3276 ft. CONNECTION GAS 30u. DOWN TIME GAS N/A GAS SHOWS AND DRILLING BREAKS DEPTH DRILL RATE PEAK BG GAS C~ C2 C3 C4 Other 3276-83 1.4 min/ft 21 u. 3 u. 2174 LITHOLOGY 20%SS: tmsl-ck, occ offwh, f-mgr occ c~r, m-wrd, occ sub ang, m-wsrt, pred macons occ mcmt cly/sl calc, cly fled pot, occ tr intgran coal/carb. 5%:COAL: blk, frm/brit-hd/brit, semi bri-bri/vit, blky occ sbblky, gtr conc frac, 80%SLTST: gybrn, frm-mod hd, sbblky- sbplty, rthy-grty occ shy, cly/shy mtx, occ intlam coal sl-mcalc SAMPLE QUALITY: GOOD FLOR.,CUT, ORSTAIN NH BITS & TRIPS Bit #5 SMITH F-15 WOB 35 RPM 70 PP 970 SPM 65 LAG 19 MIN. AT 3153 FEET MUD AT 3183 WT 9.1 VIS 34 PH 9.0 WL 9.6 CHL 900 CK 1/32 SURVEYS 2998 1 de~. Remarks Currently drilling Tyonek C coal section expecting Tyonek P coal to come in short),. Only gas show in last 24 hrs came from a sand @3276 ft. All instruments working well. MORNING REPORT COMPANY & WELL OCEAN ENERGY RESOURCES INC. DEPTH TODAY 3459 FT. MIDNIGHT DEPTH FORMATION NOW DRILLING IN T¥onek P coal FORMATION TOPS Tyonek P coal ~ 3408 ft. PROJECTED FORMATION TOPS Tyonek BLT sand ~ 3620 ft. BACKGROUND GAS 38 u. TRIP GAS CONNECTION GAS 80 u. GAS SHOWS AND DRILLING BREAKS DATE 8/17/99 morning 3329 FT. FT/24 Hr 130 FT. 197 AT 3184 GAS PEAK 236 (~ 3412 ft. DOWN TIME GAS N/A DEPTH 'DRILL RATE PEAK BG GAS C~ CZ C3 ,C4 Other 3346-55 1.0 min/ft 36 u. 20 u. 2832 3358-88 .6 min/ft 45 u. 10 u. 3466 3408-18 .7 min/ft 236 u. 19 u. 18043 3434-39 .9 min/ft 66 u. 7 u. 5142 ,.I LITHOLOGY 80%SS: trnsl-clr, occ offwh, f-mgr occ cgr, m-wrd, occ sub ang, m-wsrt, pred uncons occ mcmt cly/sl calc, cly fled por, occ tr intgran coal/carb. 5%:COAL: blk, frm/brit-hd/brit, semi bri-bri/vit, blky oct sbblky, gtr conc frac, 10%SLTST: gybm, frrn-mod hd, sbblky- sbplty, rthy-grty occ shy, cly/shy mtx, occ intlam coal sl-mcalc 10% COAL: blk-vdkgy, fma/fis-hd/brit, semidull-semibri occ tr bri, sbblky-blky, tr conc frac, abnt shy grdg to carb sh, abnt vis degass SAMPLE QUALITY: GOOD FLOR., CUT, OR STAIN N/A BITS & TRIPS Bit #5 SMITH F-15 WOB 35 RPM 70 PP 970 SPM 65 LAG 19 MIN. AT 3153 FEET MUD AT 3183 WT 9.1 VIS 34 PH 9.0 WL 9.6 CHL 900 CK 1/32 SURVEY 2998 1 deg. Remarks Currently drilling Tyonek P coal section, encountered in samples at 3408 ft. in a ten foot coal w/236 u. of associated gas ( all methane ). Uncorrected Coal # Depth Top 1 618.0 2 630.0 3 680.0 4 685.0 5 702.0 6 724.5 7 728.5 8 730.0 9 816.0 10 831.0 11 852.5 12 902.0 13 929.0 14 1003.0 15 · 1043.0 16 1079.5 17 1082.0 18 1139.0 19 1141.0 20 1202.0 21 1276.0 22 1309.0 23 1325.0 24 1367.5 25 1437.0 26 1515.0 27 1592.0 28 1624.0 29 1736.0 30 1770.0 31 1972.0 .... 1972.0 32 2258.0 33 2660.0 34 2940.0 Uncorrected Depth Base Thickness 628.0 10.0 640.0 10.0 684.0 4.0 688.0 3.0 705.0 3.0 727.5 3.0 729.5 1.0 731.5 1.5 818.0 2.0 832.5 1.5 853.5 1.0 903.5 ! .5 939.0 10.0 1006.0 3.0 1045.0 2.0 1081.5 2.0 1083.0 1.0 1140.0 1.0 1142.5 1.5 1206.0 4.0 1280.0 4.0 1311.0 2.0 1330.0 5.0 1375.0 7.5 1440.5 3.5 1519.0 4.0 1593.5 1.5 1628.0 4.0 1737.0 1.0 1772.0 2.0 1983.0 11.0 1983.0 11.0 2261.0 3.0 2661.0 1.0 2946.0 6.0 Can #/Comment Gas Bkgd Gas Hi surface hole 10-20 302 surface hole 10-20 200 missed sample 2 3 99-18 1 3 insufficient coal 1 2 insufficient coal 1 3 insufficient coal 1 3 insufficient coal 1 3 insufficient coal 8 80 insufficient coal 9 20 insufficient coal 5 56 99-20 2 52 99-24 10-20 127 insufficient coal 2-6 67 insufficient coal 3 42 insufficient coal 3 205 insufficient coal 6 110 insufficient coal 4 40 insufficient coal 4 60 insufficient coal 4 90 99-21 6 55 insufficient coal 4 12 99-22 5 200 coal at connection 8 175 insufficient coal 10 180 3-99-1 * 8 105 insufficient coal 4 35 insufficient coal 4 109 insufficient coal 4 20 insufficient coal 5 70 99-23 5 306 99-19 ........ insufficient coal 3 35 insufficient coal 10-12 203 99-25 10-11 264 Coal, dull, brn blk, shly ip, p cltd, fiss ip; grdg to dull w/bri vitr bndg, blky, mod wi cltd, brit, hd, mstly blky frac Coal Cf 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 Uncorrected Uncorrected Depth Top Depth Base 3058.0 3059.0 3126.0 3128.5 3408.0 3418.0 Thickness Can #/Comment 1.0 insufficient coal 2.5 insufficient coal 10.0 99-26 Gas Bkgd Gas Hi 11-12 87 7-9 147 19 236 Daily Report Well ID: Pioneer 170215DA Re~ort No: 17 Ocean Energy Well Name: Pioneer Unit gIT02-15DA Report for 24:00 hfs 16-Aug-g9 Mlsoeilaneous Drilling Paramekers Hook Loads (lbs)', Off Bottom Rotate: 94 Pick Up: ~low Cimulation Data: Pump 1: 29 spin 37=: psi spin psi Hole NoRun Make Model Diem Made 4 1 HCC ST-09 8.750 145 Depth Bit Information R.O.P. W.O.R. Hfs Avg Max Avg Max 5.5 26.4 40.0 3C~ Mud Log Information 98 Slack Off: ~ [~ Wear Bushing Installed spin psi Rotate Hrs Trip Hfs Casing: 112.5 g.0 R.P.M. Torque Mud Pump Avg Max Avg Wt Flow Press 70 9,2.0 350 950 Gas Drilling Pore 3184 Lithology: To Rig Name: CHP Energy Screen Sizes: Shaker No Shaker No Shaker No Shaker No Avg Max at De~th Connect. Tdp Exp. Pres 3329 1 n 21 3276 30 197 ~.% $. 5% coal, 60% ~ltst, geologists says runnning 4~ 0 ~ low to proc. ..... Rig Info~atia~ RKB Eleva~on: Solids Con~al Info~ation Top Middle Bo~om Equipmem Usage= Hm, 80 ~0 80 110 110 D~il~ C~l~ge No ~: Co--ge No 2: Logi~cs lnfo~afio~ 276 [t 24 Solids Removal Solids Removal laulk Materials Consumption and Inventory: ur=ecl This Received This Report Period Report Period Inventory Barite: 0 0 o Gels: 0 0 0 Cement: 0 0 0 Fuel: 0 0 0 Fresh Water. 0 0 0 Ddll Water, 0 0 0 Truck/Boat Status; Drill Pipe At Location= DP Sloe Joints Weight 4.5 150 16.~ Rrst Aid: 0 Medical: 0 Accident Deaorlption: MeetingsIDrills Time Description I~ BOP Test Grade Thread E 4.SEH SafeLy Information Lost T~me Aoaldents: 0 Days Sirtee LTA: 17 I"[ Cmwnamafl~ Check Page 2 Daily Report WelllD: PioneerlT0216DA Report No: 17 Ocean Energy Well Name: Pioneer Unit #1702-15DA Report for 24:00 hrs 16.Aug-99 Operator; Ocean Energy AFE Nos: DWIS01D - S328,220 Rig Name: CHP Energy Spud Date: 29-Ju[-99 Days: ~inc~ Spud: 16 On Location: 17 Measured Depth~ 3329 Previous Report Depth: 31 Drill Hrs: 5,5 Last Casing-' 9.625 at ~75 Personnel: Operator. 2 Contractor: 1 Current Operations: Planned Operations: Toolpusher: We#site Supervisors: From To Elapsed O:O0 $;00 6.00 Code BOPOT 6:00 B:0C] 2.00 SERV 8:00 8:30 0.50 BQPOT 8:30 12:C~0 3.50 12:D0 15:00 3.00 REAM Field: Pioneer Unit Total Well Costs: r~19.778 Total Daily Costs; 824,537 Mud Costa: $600 Tobal: $17,685 Total Ver'dcal Oepfl~: 332g Hole Made: 145 Average REP.' 26.4 7.000 at 4100 Last BOP Test: l$-Aug-gg Service; 8 Other: 0 Total: 21 04:0 5-17-99, 3~t59 rot held locked up, pulling ret heacl assembly, 15:00 15:30 0.50 CIRC 15;30 19:00 3.50 DRILL 19:O0 22:00 3.C~0 SERV 22:00 0:00 2.00 DRILL drl9 ahead to TD going thru transfer pit Mike McNaughton Dennis Ackerman .,, Operations Summary ..... Operations Description test hope 300 law, 2000 high, teat went well after repairing arease ntpp~e CDL on kelly bigck irlstall wear bushing 13u NB ~4,, tih wash & ream 3004 -3184 washed d~n hut bit was pluggea when tried te dr elf bttma up p~or to drilling 3~84 - 3277 g3 fi; :26.57 fph replace tubber and seal on rot Iqead, 3277 - 3329 52 ff 26 fph Comments rot head seal leaking thb evening. Rel~aCe seal and rubber and ell OK, But at 0430 on 8-17-98 mt heacl locked up. Will have to dril~ thru transfer pit as no rot head available Density Vis kit Cake PV YP pH 6-Aug 21:00 at Dep~ 3339 9.30 3a 6 1 7 8 9 Mud Informatiort .... % Gels $olide Water Oil Sand Chloride qOs 10m 30m §,2 94. B 0 0 12~0 2 8 14 90,0 85.0 Mud Consumable Items Item Description engineer. 1 man ReP From To Avg 3184 3329 25.0 Qty, Cost Itmm Description t e00 ., Drilling Parametem_ weis RPM Tamp In Out c~ty. coat Max 40.n Avg Max Avg Max 30 30 70 B0 Torque How Avg Max Avia Max PS1 ~40 ~50 95O Page 1 Daily Report Well ID: PioneertT0215DA Report No: 17 Ocean Energy We~l Name: Pioneer Unit ~1702.15DA Report for 24:00 hfs tG.Aug-g9 Sky Condition: Air Temperatu re: Wind Speed~Dir; · pc 65.0 dog F Weather Visibility: B3r. Pressure: Wind Gusts: Pri~ed: 7:20 17-Aug-g9 Page 3 ~?0)24:{.:)~44 MORNING REPORT DF, VI'EI '?OD~ v !f,{ .I FI'. Yl:.,.q'l I:.RDAY.~ DEPTH DATh 8.q 2 '~'~ FJ';24 H~ .,~.{...F..F,., ............ ):"ORM A.?ION TOP~ ¢. (.)h~i,,,l~(..:TlO~ OAS Ii) u. BIT,g & .,~ IPS ' · ~'OB 25 .R. PM 70 PP 'L~) SPM ~6 r. AO 15 M'[,¢. AT 1770 FEE'r I [ ' - 'l II{IllI II'Ill, Il IIU , ,mm.ii~,i~m~, , ,~.l','l, llll, Ill, } --' , ~ , I , . · II ~ .... ~--, mf~,,- .. , -~, --,.}~ . iii Il.ill .illl, .~ !Ot~.NING REPORT Daily Report ~l~ll; Pion~ 4702t~A ~ Oc~n Enemy MD: ~ A~~ Pioneer Unit RJLL 9,625 11 ~~s~. 7. at 4;~D MD, 41~o'rv~ I I I Jill -- '- I I -- l lll ., TopMD III I IIII ToW: b !---I _ mmv!__ I-- · - TUBULAR INFORMATION lure MD Top TIi~ ~r, _ _ __ I ..... III ........ I II _ WATEREE MUD 3/5 ~.4 0 1. 4 ~ ~6 0 o 0 ~ ~1.1 II I Sff ~ lB11 . ;~,.qO $4,8 / 70 __. II____ ] .... '-] -- '- I I III .... Ill III Bill lit .... I - MD Inc. Azlm. I I II I~ i~_ . Ill ./ DRILLING PARAMi~TP. RS we:lB ~M T~ ~/ao 7o t ~ / ~,~ 7o,~ ~,~ II -- ___ III IIIII II H~~UC8 INFORM4?ION . . ' ...... ll ' I f_ .I I ~LOW PUMP DATA Pr)Il - llll I I .... [ ' I III ..... SURVEYS .. , , ,------',, lml~l__.ll -- I I ..... I I .__,,l ~PE~TI~ 10/~ II I Well: Pkmeer 1702'i6DA ......... _ .... emil Pioneor Unii ~170~.t SDA I I Ii llnll MUD LOG 0.4 ~L( W:)TATING IM~t Mhle~ DC,I~I~,~C,I~C,DI~,DC, DI3,DC,I:IC;,DC,I::C,D~,DC.DC~BIT · 422.54 I ---m . _ III ....... MedlcM: O 0 I:~.y. 81rice LTA: 14 L-.? Im~, Tm ~ II ---' I LOGlb"11CS UMd Rcvd ;klm O 0 0 OMnonl o o o Cmt Blend o 0 Fml Cl 0 O Frmllt I~ o 0 o JdllWtr 0 0 IIII I II Tdp Pm, e Pf,~g 72 .... I I II I ID7 TMaI: da~g ~ Gl'ak Ca, aa Mul)i41 4J~EH · · rue & nAe6£ s'r-ATUS .._ il i . JL_ml m. , iil_l i .- r' CC3M M~q,IT,S Unit Daily Repor~ li~lill: Pkmeir 170218DA OIwmoc. ommn Energy FSek~ PbMer un. · PBTVI~ D~I~ WMt G41m $I ?,ABf ~ ~ G4m: Pray, DIIXh; 24~0 gm AFE ~ ~D77 cum AI~ Cmtz: DINI HIw: 11~ TM Mud ~4)4~K S15~3G 'TOMI Fluid Cmil~ Avl& RI;~P~ ~2,,1 Gum Well GMM: Ocean Energy i i i iii __ i Rig Nmm~ Clip Enrac, ~ I'~m do bit hip M p-mn hu ~w.~d. Ifdo, wilt im~ (==p's ~s Ixr rq~ even, 7 d,~, T)'Fe Mm TOlHiD TI;MI; O TUBULAR INFORMA'nON BImMD TepTVD mmTVD ;;75 ]1 ...................... -' WATERBASE MUD REPORTS o ~ 4 4~ e6~ o o o s.5 a.~O,Wl.2 "'-~TJNF~ RMATI-DN GItNo Dim Nil ROPAvg WOB RPM -~'flJr OA 24g0- 2~K~5 22,4 / ?0 NO Itydrlulk~t m/MIIW~ I~ t~ mpm'C · . II I MD Irk% LTJnL ...... IIIII III III I I II I II DRILJ. JNG PARAMETE. R,~ (AvglM&x) WOG RPM Torqw RMM ~730 70 / 76 / 7~i. OO II II .... III ............... I · H~'~)RALJUC, S SLOW PUMP DATA- Rate t FSI 1 Rate2 1~12 Pump 1: 20 2EC) ' .... SURVEY8 OPEI~TIONG GLIM MARY Prod OpulmnS ~ t~.~ ~'OD ~ DRIL~. I' IIIII 7B,00 74,00 .--. .. =ii I Ill l I I i ii ii i ... iii Daily R~part -- 1,I -- -- I II _1~1 III I RMallntl I III III .. _ I Trip 8HA ROTA'nNG Hi~: Sinci impede; 12~ TMM: I? DP I~5 ,~ !6.6 [] EOPT~M [] GlY~mlmilk~Gheck LO(2JISTi~S ¢4y: (~udy VIL:$ __ Il /I I)m I I immmm · , , IK)~T, Tu6 & B~i~E STATUS No BoM Sm~ i2iMI~ ~ th~ mlF)ml. I~G/WEATHER INFORMAllON m(~ GevMkw: ,, ..... II Ternp;55.0 Preslum: Wind: 4,1 NE ~l;~ Iw. ll ~ / Wive. _ Ill l III I~m~l_t re_l_ _ lU ii. mil ..... _.m~; COMMENT~ A~u~. iS. 1999~ MQ!'~ ~T"~C R]-:,PORT Pioneer Unit #474~-If, DA Umw, c12~X IMII:Maj/oU~'. BT ~T 481o LCn' ~ #~1 IkllE: PR RM4~ 7O / ~ / 80.C~ INFQ~MAM~N II.12W PUMP DATA P, il I Nib I Pljl nl(~$ PlIB NI ~W Ved~M~ D~I ~ ~CERM ENERGY RESOUrCe5 · ,, -~- __. , l, , i .........~, Ocean Enm~y Plwr Unit 111111~-411~ ~ No:, 1~ ~4,-00 hr~_ _. 1 _&~m~ag-ml ---- . ..-- _ 1. , _ _1 ......... MIlD COI~ ,G,4 tl ~1 · ;14 --- -- , , ,, , mm _mll.. I .... I I mi .... I ..... _11 II I Illl BOAT, TUG A BAROB IIIT&llJI 1~o IIInM ~ ~ ~ tm~iu report. WaiVe KG MORNING REPORT DAT~ TODAY p~__~ ?~_.___.. YI~EI'ER/DAYS I~EF~H FORSEATION NOW Dgl'I..LING ~ FORMATION TOP$ GAS N/A AT CONNF, CTTON GAS N/A DoWN TIME GAS N/A ,., .~--..-.... - ~.,...~, ,,.. ~,...~..,,. SURVEYS . ' 24:~0 Indum'tal Grand SuucJk~ C~elorado ,MORNING RE?ORT r, ff,'.PTE 'l-t ~DA.Y J 5..~ FT, YESTERDAYS Ol~P'I'lq Tr.' (.ONN't.¢ I'ION i..~A$ I..=~ }!;. ........... DOWN TIM~ ~A$ ',N~, t ~45.~ "i.~ ' '~ .... :''" ~ ................. ~ ..... -: :~ ~' ~ -' ~ } ~l ~ ~ t ~ · .......... ~ L 1245-62 ~ 1,1 ~,'~ ~ $6 u. tvl. 1_~7.~ ,309-,., i .8 m~ ,~ : 172 u. . ~.. ~ 1,206 ~ 143C-41 , ,5 m~"fl i 175U. ]u, e!7' sl c',~lc, eh' fl~c[ 1~o* ~ f"Ad,~ o~¢ tr ir, tiaz~ en~ ea~, 30%:~.OAL: hll~ firn,Bl:it-hd/brit. ~m/hfi-bri, M~. ~ee ehzll . ,.~, .y. ,~..~4W__o:.~c .s,~ii.g2.. _.r~n,_,_?,~_~a. E{! ............. $)3,'i ,PL: QU.M2TY: ...G_O=O D ............ g!'rg a TIt.lPg WOB ": Rr'M ~,-,,.,~ Pl~ .'.50 .qP,~,! 65 k-kG i5 MIN..AT ~561 .KUIL, r,~. Y ~m~m belly btu n '~'a~ nm pos~bb. ,~as l~,el~ :~ld b~ di~h{y ~r~4 due to n 10 hN. open ~.~ldi~p -. ,~..~ . . ~.,., ..... ,,., ~,.~~~,,_~.~..~,. ~ i Dally Report Well: PMaeM' IT021~DA Ieli 1811 NMe Made; 361 I~ll Hrm 11.5 Avg, IKI)~ 24.4 i. Mt ilM' TMt: ~-OO Cm11MO~ Willliie lu~; I::)enn[eAok~Mman FU'.J. 9,625 :L:I. Cean& ~: ?. ~ 4t00 IdD. 411~D'rvD pl'r 1'~8 8,,ID ~ 7 37 T.~, Mk. McldauOl~on OIIW:O TMM: TUla U,I.A,R I~FORMATION mm I~ TM'n/D mm 1'vD ~75 ~2 675 ~~ MUD REPOR~ ~ ~~ ~~wa~k~ MBT ~ ~M~F 1(3.2 lilt Illin 2 1 e.'75 ~TC FI(3T 11)116/I~111/! L.R 6e2t 113~S DllilkOul: t811 CullaF:llmMl(;klla¢. I 1 8 Dull:IN/Oil, BT / WT :) 1 B. TS H¢C GT-OO 1FaqSi15/l#l (312130( Hnl ROP A~ Woe llP14 W#uLa¢4 H ~ E ~a. ll~: 1 LOT Palh RIG DRIL4JNG PARAMETERS (AvglMIur) O~ R~ ~ Ko¥ ~ lief Wt IqUWt ~lOWt 530,1811 243 ! 70 2~,'~' ?0 / ~0 / ~,00 ~lS.00 ~,00 HYI3RAUUG8 INFORMATION 6LOW PUMP DATA Punllp I; 31 ~]0 SURVEYS Mi) tn=, Azkn, TVD ~ EW Vm~l,~. D~ I.~ Ne tam fliidlflll fef thll rillelt OPI~IATION5 ~UMMARY O:OO !;,~ I~EFN x oMl~edb.~nt~kxk~.(~lr14~,,3Ml~2~, ~i~thwl2hrLnunew~rM~W~ 214 Will: PldZFJMr 170Z18DA FIM &M: o Lod Tram AKIdm~, Am:idld Dl~: Total AlWH~ Jarl Below J-r~ lli¢l~qm ~ i. il~llh &bi Wtdolll MedT.,ll~ C) ~ lOP'TiM ~ GrowMmMleCltlgk ....... i,.O~IItlTIC; ...... ~ 0 0 0 emi IIm~ 0 o o FuM 0 a 0 Frmeh Wtr o c) o DI'IIi 1Mr 0 0 0 " I TM~ Ill No OdU ibtq Od.k M fha mI.Xt ....... II IIII I '- -- RI~THER INFORMATION RKB Eiev~lm: lltM,M(cNnll ~ r~ head ndX4r~, drillkl 4 ft .~ bU,'lnp~ t~.kad up. Deckled ID pooh.nd It~td new ~ I1w~d. Fof~ ~ hM ~ ~ tufvIy. HM ~ ~ ~n, no ~1 ~ ~. W~U: P~aaw ~To215D~ Pioneer Un~/l?OZ-18DA IIIIL_ - ___1 I -- Jill -[ I _ II1_ i!-- - -- ~~!~: ~ C~12 ~:7 ~O ........ ')'odpu~hen Idlb MoNaugl~n 6be C&qi~G, Ndxr; 7.1~41C13MD, 41~[)TVD ."" ....... II I- I~ - PiT ~6 9.1 ? 8 ~ 3t10 10.4 ' 0 2' 4 ~ ~2 0 I --__ ----. I~ -- _1~ II I I L ~1 II ~ ~ ~T INFORMA~N ~ MD~ 41CX:) AMIh TVO: RKB tO ~ RI(B m Gig tlMd: RKGIO ~ wMoeFm: ~ Ill __._ -- ~ MD TOp 'rvg ~ '/VD IJ3T 675 ! ! ~75 I~ ..... I ..... I~ -- I _ ~ ~ I _ mm _. ~ ~ ~~~ MUD ~POR~ _ I~ - £l I _ I I I~. II III I _ I I -- I I__ II _ -- I- - IlL DR;I.L. ING PAfU~M~ t 2~25 ~ / 70 t 4~,00 ~.O0 _ - - JL--- . I IIIL-: _ I - III I I ...... . ........... I i Dm u'ucs Ill -.. n[[[:[ lB - Ill L Ill _ -- -- 8LOW PUMP DATA this L~. II I L_ J - ' No Survey R~lldiltlS lot thil Fmm 200 3;~3 ~.~3 DRILL 3:33 4:00 m_~ ~URV 4:(::]0 11 .'qo 7j33 DRILL ~:~ ~ o~ ....... SURVIEY~I NS aW VMU~M:~, D~ L~ ako~ure 11~3-1{~;~) 34.7~, 22s.gf~ I ~ ~ :pm Daily Report t2 TM&t: Fit'lt Aid~ LO~t Tkl~ ,I, geMmlt ~ ~ ~k~ TMt L,~ Crmmalm~ clmck I~1 Nll~a; CHP Ef~g~ Ocean =,4;1)0 kt~ ,11.Aug-0~ .JI I Trip: BOAT~ TUG & BARGE ~I'ATU9 ~Gt~NE. ATHER INFORMA'T1OM RKB Eknmtk~, 2~ ff 41/2 r;:~lllng ~ mi:dyer ~g ~ ami around 41,'4' ~uam Mily. wll mw m g~a 31/2 nd.b~ ~ ~ If can't get tMter Operations Activity Summary Well ID: Pioneer 170215DA Well Name: Pioneer Unit;i~lT02-1SDA Hm Gocle Product Am:IvIIv Dem.-ftl~lon ii 10 09.Aug-g9 0;00 16:30 16.5 REPR 0g-Aug-99 16~ 17:~ I ~T 0~~ 17:~ 20:~ 2.5 ~1 ~ 2~ 21:~ 1,5 CIRC 0~u~9 21:30 22:~ 0,5 ~ LOT O~Au~g 22:~ ~ 2 C~ Ocean Energy Page x i~taTI rotating llucl and aMoelated plumbing. Ill~'tal wear busNng pu n~ ~.., 3 d~ tlh, ~g cr~t ~ ~1 k~ ~ dD. in~l mt a~ d~ b~hlng on ~ ~t ~ml~d c~ and m~ C~ mUI ~le ~a~ up mst~ to l~O mi ~r30 dr~ ~ & float ~[ ~ he~, t~k 5 h~ · get ~ ~ fl~ i _ t i l AUb-II-~: mm . mi I iii mi . _ I _ m ....... Il I mlml . ~ LLS'T'RI Ni3/~A~NCB W~..&R Tm'il) BN& W3TATISI IILI: Mnce~; 54 T~al: ~ Tkm M~lc~ts: 0 Z)~ylr $1f~ LTA; 11 Ag~ De~l Ra~m~ R~linl~gh (flmx, hmnd) r..t thumb m- il. · mi Trip: __ m Ill mi III ..... l_ ' .... aOAT, TUG & BARGE 5T'ATU5 2781~ -- MGAN~..ATHER INFORMATION IL. S~k¥: po Ms.: 25 TMI~.,8~,O Pin, SOl'e; -' m~ _ i -- I il ._ ii Wind: 5/0 Guat, t; &'wag ~ / i iii mil I i i ~DMMF. NT~ - Re~m bi i~fQ, i'.ven~ flg~nd c~ hMt~ [lit dm t~ Ba:ipI: b~. ! ~ lin but I:lnt FJ In he chi~, Wit1 ~ hetp Mt hit ~11~ re.miN. wive HI: . Daily Report Opwrlloc Or, Mm Em~gy Plrro: W&w Ilumhh~i Im ~ _ mo mm~:' c~P ~ ..... · I m II I ._ I ---'~.1 ] _1 Il L--. _ I I II .. Ptmtftld Dpm: d rlla I~ FJ~C), ~ =m~ ~ 1 CZ]0 t~, dd ~ue i~110 ~ new ~o1~, 1:4rf~m FIT to 11..% d~ .lNdd u per pr(~rlm Wder P,N)m: mm i. - - - I Il III ._L .... I .L I ' ...... J DRILUNG PARAMI~Ti~RI,, (Avg/MlX) I:)lplh ROF WOil R]I'M Tm Rd ~ "-'-" '" --"'-' """ '"" ' IdYOiU~UUG~ 3~.00 i ii LOT No I~dr~__,!~m Int~H~_t_t~n I'M imm rupert, .. - JLa III I I II I __ Gblr GA II 3~,00 II I I I N= alow I~ Data Far thll ........ .... 8UK~EYB t~. OPERATIONS IIUMMARY install wm I~k'mg 1~ ~b ~, ~ d~, tth, tall ~ Ol SB1 16 em dp, Inmlll raL t'Md mhd dr~ t~ml~ing ~ tWly clr out ooftblmlnlerl ard Ind mud, Cir u~tjl h~ Ollini up tsnt c4~ ~ 1sc:o pN 1~,3o min. drlg cJ~ & ~oat cmt ~ hNrd, ~oo~ 5 h~'~ g~ thru I~ l~llt lDaily Report - '- : Ocean Energy ~ ..... ,,,, ,. ~-.-- ~ . . ,, .,,.i . i MUD ~ . i .,.. I II .--.I ~ ' ~]J IIII laHA/DFaL.L3TRINiWCA~ Nql lIH& ROTAlqNO 1Mi: linee,loepedbn: 33.~ ToMI: Tdp I,Q~P~ ill Alanndmn ~!11~ P~ Trip; BOAT. TUG & BARGI~ STATUS .... T I I . L II II .I ]L~ I I _ I II .. III ............. .. " ' = "'L~ . RIG!/WEATHI~R INFORMATION ,, ,,,, , , .. ,,. ---- ._ COMMIT" " ....... ,, ,, ~ ~ wl AOGCC ~ ~ ~ ~ ~lng ~d ~ up, ~ ~i~ ~ ~ ~ In ~. ~ ~ ~ hard d~ to ~ d ~ t~. ~OO C~ dO~, G~ ~ ~ ~ ~ OD ~ ~ d ~K Mil ~ ~. Type ~ TopMD FULL 9.625 ! :l ClIMi NI~, 7. · ~.. · .... .___ I iF~ ~ ' "I .- - ND B~ Ill~ltio. for WI~ ~ I I ' II II 3 iii Ocean Energy Report?o: 1t 24:00hr. 10-Au0~ -- ' ' II i il I~g NMlw: C;HI:) E~prOy Tc~l fluid Co~: G~WM ~.. t,4~,~ iIm . _. i Ii Auth MI~. 4ICG Adh I'VD: 41C)0 RKB to M~ ~ ~ lo Mm., i *-- II II TDeipulMr: ~ Mg~ugh~rs I I T(~II; 21 TUBULAR INFORMATION 675 21 WATERELA~E MUOREPOi~Tt WI. ~~ ~~sW~~ MBT ~ ,0 2 4 ~ ~ 0 O O 10~ I III1[ BIT I~O~A~ ON Jail WOG RPM DRILLI~'G PARAM Er~R~ ~M TW ~IlP~ 65 / 70 / 9,00D.O0 I ...... I I II HYDR~UI.IGt~ INFOAJdATiON p/u~ · . I LOT mom 8,000.00 .000 t --. _ . __ i.,,-- Ill I ...... No Sun,~, Rmadlligs br ~alm fill(il'l, Imm- ---II I II __. ,II ____ .I I ~LOW PUMP DATA Rate I P~l I Rib Z Prd 3 RMI ~i PSi t i illll I I . -OPERATION3-SUMMARY- OM'rD C/LOT CM'rD DRill. C/LOT DRILL 8ERV DRILL REPR DRILL I mm ........ ' il 1 Il lll i1~, I . _ _J _Il: ' hpOCE~H EblERG. RESO~RCE.~ ~ ~C' ~7 ~73 103~'4>~ v.e y. :5 i' Dally Report Will ID: Pioneer R~port N~: ! _ Ocean Ene~ly Well Nm-J: Pioneer Unit lJlltl~,,'l.~DA Aid 0 MmfngJ/Dr~ll, Time I:},~arlptlg~ E 4.SEH Id, tV I ntermltlon ..... Lo~t Time Ad:c:ldenlA: Villbllliy: Bit. PMl~ure'. i,, ?, 2 Dally Report Well A.rE Nos: I:NVISD1 - Spud Da~: Sim ~d: PmViO~ ~t DHII F~m To GNP Enargy 2g-dul,9~ 875 l~ln0 r~ held, inmMling lin~ fram ~ BuYer ~ fi~ line in.t~l rot ~d, ~M McNIuGM~ Ocean Energy Total Villul Dtpth: Hole MM: 7,0OD ~t 4100 l~l~t BOP Teit: i im Non.Ptml O:01:) 8;D0 8.01:) BOPOT trot b~pi, =hake maniteld, ma~ I& kill Line, 20~ high 3~ l~, ~nufer f~l. ~ ~mu~tor t~L ~Me~ ~ AOGO~ Ltrw We~ 8:00 O'.00 !6.00 REPR nd lnnUlg, ru ~ r~ng had. x ~ulp), m~ end ~d up IIMIo ~ b~, ~P ii ~ng In an ~nullr ~ ~c ane ahead ardve &1~. A Grant ro~g he~ I~ ~ No~ 81~ m~ml~g ~ 8~ ~d l~d ar~vm p~r~n~ ~ 1200 noon ~, T~ d~ve ~ ~d ~cfor it ~ now In P~rban~ ~nd ~ i~ H a, .r~v~ tt ~ ~ ~ouoM ~ Ioa, ~~ thlt ~ bi ~ng ~ ~e-~. ..................... Mud I~matl~ ....... ---- · YP pH 6~lid& W,~ ~il ~ C~Mrl~e qO~ tom ~m I~ O~t DeMitt/ Vb Flit Cake PV 08-Aug 23;00 at Dlpth 975 8.70 ~4 14.8 1 6 ngi r, 1 man Equipment Problem 4 8.5 2.7 97.3 0 D.25 gO0 2 .. Mud Consumable Itame .... - .... . OW. cml I~ D~I~ I OOO _ _ R~ In~m~on .... a~nul~r f~ilM bop ~ wau~ h~d u~ ~ O~ ~. R~ ~e nu ave~ 2 3 62.0 0.0 qW. aa~i iii i Salta/R~avd 8alld~ Remove/ - i · - m __. -:: ' m i Pa;p 1 Dally Report Will ID: Ploneir 170218DA Rel~rt bio: I -- 1,, i - Scr~n 8be~: 8blklr No 1: Si No ~: 5htkir No 3; 6hmbr No 4: Ocean Energy Well HI: P~Ir ~it Rtpo~ f~ 34:00 ~ i ,_ , i i ..... _ .... i i I i .... ~l~ e~'Gl I~~........... Top MMdlt ~m E~l~IM ~: Hm, 60 50 50 ~!0 110 ~~: ii ii ' Bulk MiWiBI~ G~sum~ I~d ~: 0 o 0 ~m~: o 0 Fu~: 0 0 Drill WiW: 0 0 O TruGttJBMt ~tus: Weight Qmde TitIlII 16,6 E 4.6EH ......e~i'ety Inform.lion .......... DJlYl 8~B LTA: ..... iii iI . . i L Daily Roport W~ ID: ~~ 170~1~A ~rt No: I _ ~E ~: DWI901 - ~t ~lng: 9.625 ~ 675 N~: 7.~ ~ 4~ Plan~ O~at~nl: ~niJh re~r, ~t T~IpuJ~; M)~ M0~ughto~ From To E~ ~ O~=n~~l~l~ Ocean Ene Well Nlme: Pt(madr Unit ~170~.16DA , IlL . ~ I - ' r _ . ., I I T~I ~1~ C~b; $23,170 Mud ~ ~O0 T~: J~418 Total vJ-t~l B.l~: Hal~ Made: Averaoe ROP: Urea BOP Te~t; _ --__, - II I, .I-- Nmn.~ad O:00 0:O0 ~.O0 NE, PR wi~ on bop parM, t~r m ~ m g~ ~ ~ehorage 2~ he, ~- X =--, '~-: ..... - - _ , ~ml~- , ................. it ap~re t~ ~ ~e ~lt ~ ~ I~e ~, Th~e~ ~ ~ r~ul~r ~h t~ ~mula~ ~1 and the ~ vJiv~. Wh~ ~er W~um~m rig hydriufl~ Md it ~M ~e r~ ~mmure m wh~ o~ a~ M~. Norm~ you kmtp ~he ma~d ~um ~ t~ ~ill ~m ~ ',1 ~ mt 2DOD ~ 3~. T~ r~mmJ~ m~ pr~um ~t~ ~ i~ 1~ and ~ hid up ~ ~1~ on ~e ~g ~m~li~, ............ Mud In, creation ~. -- ~ ............... I:~nll~ Vim Flit ~kl PV YP pH ~lidl WiW 0118l~ Chl~Me IQ& tom ~m In Out O7~ug ~:30 M ~h ~5 8.70 ~ 14.8 I 5 4 8,~ 2,7 97,3 O 0,~ ~ 2 3 3 ~,O ~,O .~ _Mud ~a~ll~s ......... -::. . ..... ..... RI9 ln~mafl~ ~=._ · ..... _ , ~. ~- - RK~ Election: ~6 e ~IUrl, ...... _.1 ,ILL __ I l~m Dfl, m'l~llm,t eBoln~- I marl Equ Ipm iht Problem W~ll ID: PIo~r t?021SDA Rsport No: ? Grar~. Tkr~d E 4. SEH Sm~y Infarmatw. _ ---- _. ....... - --- _ 1.4~t TlmsA&~idint~: 0 I~l Wh~ LTA: __ Sky ~ndllion: ct0udy ~ oco rgi~ Wind ~DIr: I I . III ... '-- Visibillt~: 10 Bar. Prmseure: O t'OCEAH EHERG"T' RESOURCES Dally Report Will ID: Pioneer 17021H3A Report No: ? Oi)Mntor: AFE Nos: C)~i§o~, ~372,367 Rig Name: Spud Dints: l:bws: Slam Spud: ldmeumd D~pth: !:~IIi Personnel; Current Oparitlofll: Tmdpusher: --- _ From To Elap~4~ll 0:~ 1'.00 Ocean Energy 8 On Lccml~on; 7 O Next; Ocean Energy Well Name: Pionosr Unit 8t 702.15DA Report for 3&:go hfs 06-&ug.ll Ill _ I I _ Il I _ . II _ Field: ~onoer Unit Total Well (:~eto: $340,~41 Toba Dully Co~s*, Mud Co~t~: $806 Total: $11,616 Tolol VerUcal Depth: Average PJ3P: 7,0~ waling on pa~ for ~, aa eoofl ~ ~p .a~ arrive ~! ro~Ir t~ ~n~nue ~th ~il Mike MnNau~ht~n · - - .. :-. O~ationi&umm~ ---- ,-_ --, C~e O~tlofls ~i~on ~EPR ~ for arrival 675 01,Aug-Og Total: 1o Non .Prod X I:00 12:00 11,00 NU/ND nu efln~lir, flflleh rest ~ ~ 12:00 O:00 12,00 REPR ~~t~P~ ~t~ ~8gone~m mm ~iont, ~u~n~ X g~ any ~ MI have ~ fly ~ iff from I~r 48 ae no e~ ~ila~e I~ ~, did ~ ~ ~g ~ ~ ~it ~ile ~l~g for ~. Omi ~p ~0 h b~ h~o ~t to ~ffe~ the ~nd log while ~Wng ~r ~ ~r mine. Top ~ ~t ie 220 ff ~ ~ ~ve ~ iudt~ In the ~ ~thout ~r~Nng ~e su~a~ ~, ........... ---, ......MUd I~~ .~ ..... - ,-.- _ ,, Ods B~fls~ V(~ FI~ ~ ~ YP ~ ~IMBW~OiI~ CM~t~ lOB 1~ ~m Iff Out 8.~ 41 13,6 1 12 8 G 3.6 ~.I O 0,25 GOO 2 2 3 74,0 O.O I~m ~lptlon Qb, ~st t~ ~l~n O~:o OF - 2S~ hO 4 2~ en~n~- I men .~ ~ _ ............... RIG I~orm~n ............... Equt~t Probllml ~p rum failure, the ra~l u/Il am o~. Can.t ~ aW in AK to am ~lng ffo~ Aug~ ..... ._ ;. ~ ....... ~iid~ CocCI I~ma~- · ___. .... .,_.-~ _ ...... ~ al~: Top Ml~e a~om Equlpmnnt ~ ah~ No I: 50 ~ 50 ~d~: .~ No ~ 110 110 ~ilt~ Shak~ Nm 4: C~M ~ 1: 8elam Rom~al Dally Report Well ID: PlonNr 17021SDA Report Ne: ~ AFE Nos: DWlg0~. S372.3B7 Riel I~me: 8pud I~: Dqfi: ~Mnae Misai~rod Uep~k: Pr~vloun l~l~or~ ~ltl Nra: Plmn~ Tdllt I~#¥ CPMdi: 907 373 1338 -. Ocean Energy Weft Nm.' PJonltr Unit iH 70~-tBDA Report for 24:0o hfs Gl-Aug-Il ii ii. .--:. i mt . ,Him Il PlMd: Pioneer Unit TolM WMI ~t~: $22.9;4eS TaMb $8,010 Tolml Vertical Depdh: 14d)~ Marlo: AvMIgt ROin: 7.000 mt 4!00 L,ut BOP TNt: 01.AuG-Q0 Conlrmotor: 12 Sirvkm: 7 Of. bM: O T~I; tm~l~ting ball nlp~ ~ prN~ eme. flhilh nu, t~ ~p, run cmt ~nd log. RIh t~ ~g, grl out c~ & thee, 40 ~ helm, WeUmlm ~u~v;~: Oenn~ ~.rmmn ,~ F~ To elm~ ~ O~mtl~" ~l~lon ~:00 21:00 1~,00 ~ND ~ 1~" a M~LWS Ram, [~fl ~oKe Ilne~ HGR ~ ~e~f~ flne~ &~ 21:00 0:~ 3.00 R~R ~lt on annular the ~ to uno= ~r r~t X & ash, 9 hr for ~ ~. .; ~nal~ Vim FI# Cake OS.~g 23:00 at D$~h e75 0,00 o 0 0 Itlm Ehkl4~'lptlon e~oJ,n~r- I man ~k' L~, C'~:' Ml~flll Off 1~3~m b~Jto; Plok U~ SlllOk Off: ~ Wee' IlluiMnl In~MllMI AUG- ~.-~9 FRi 5'02 P~I Dally Report Will ID: Plomlmr 1711Z1~iDA , , Lggim;6om I.~orm.llon ..... Bulk M~tal~ C~um~LI~ and tnvl~: Ig,~ 4.,SEH , . ,~a.f, at, y' Infm'mailen _ ..... , _ ,, i,, O CM~t TIm~ At. dents: 0 O ean Energy ~ Crown~ma~l~ Cheqk · _._. -..-~.'ii ., i i i ii Yeel4ngitOfll,lA Time Dil.orlpt~on ~ BOP T~ ....... ~ Il . . -- j~ 5-99 4' ,6 OCE.L'. -E EGR%', ;.K FAX riO. 907 9?3 iOBB Dally Report Ocean Energy Will ID: Plonger 1TO]lSDA Report No: S Ol:~at-~. Ocesn AFE ~; Dw)g01 - Rig ~me: clip ~nargy DI~: SW Spud: 4' On L~tlon: Drill Ws: 0 WeB N~me: Plorflim' Unit Itl Report for ;14:011 ~ 0t-Aug-il Irl~cl: ri o~eer Unit TotM Well Coe~i: ~oe,oeo · tlatM Dilly C~te: $t 15,60:3 M~I C~M: $818 T~M: $7,410 Tobd Vertloal Depth: Hole Made: AvMaEB ROP: Last Callng: NeXt: 13.3'/'~ at :~ I.m~t BoP'rest; 01-Aug. O0 PersonrIM: OFmrat~r: 2 C;mtragl~r:. 12 Servlog; O Other: 0 Tolal: 20 Ourre, m OperBtloni: · 0430 ch3rle wMding on wiMIh.ed and latttr~g well head oecd Planted OpMmlon#: ~ll nu bop, feet ~ame, run bond T~Mpush~: Mik,i WeilBIt~ SuF~rvIBors: Dennis Ackermsn Doug WIl~n ............. Op4witloltl Summmy .... To Eiapf~l Code O~~i ~ :00 ~,~ TOH LD r DO 6;00 T,~ ~E RUfl~sJ~g~83MJ. gSSTO,~rkt~ru~l i~105~r~4 turn a~ went thru i~ ~d =on't to ~m w;o ~D~aml, in tenilon on ~m 6:~ 10:30 2,~ OiRC ~r 10:~ 11:00 0.50 OTHER h~d ~gj0b g~feW m~0 for cm~ng. ~11 ~al & r~n ~t:~ 12:00 I.~ ~MTP omtwi400~Gwi2~;~, l~x~gm~, ~.1~, Murw. ~O D~g ~d cmt ~urn~ t8:00 0:M ~.00 NUVO ~ o~ ~, nd ,, ~ ~ ~ ....... , .... ~lhg ~lhlld ~oi ~ ~, In~all ~nt ~, ~!1 Itlg flu ~thln · ~pe bm, ~t dme ~r (n~O ~ Ingtmli ~w~ vmlw ~or HCR), ru~ ~nd log ~ hrl, ~ bhl ~, 2 hri. T~t mO for !~ hr,~ drl ~t & pr~mm RT 3 h~. Th~e ~m~ Ire ~t ..... __ ,. .... , , Mud Inf~mallm , ,- Yp ~ 6olld~ Wtter Oil ~nd Chl~lde 24 t0.2 6D,6 0 3 l~ud (~2neumlbl$ Iteme , Go~ Item O00 O~ - 1 103 .~ Rig In~ma~on _ ,-- RKB E~vation: OMI Temp 10~ t~m 30m in OUt 7 18 25 9 0. D I · i 276~ Density Vie Flit Cake PV O&-Auo 2.q:3D ~ ~ept~ g.7o O0 I0 2 '~'9 Imm O~oriptlo~ ~flC]lt~eer- ~ man Deco CF - 2~ beg iii ,11 S',. 'J OE:!" 'C'N S-qC,~FIOS-q;~ .I ~ ~J~F.J~_ Hd3"_ ',~ NW~F. .....: ..." 666, T ' c ' m,-I~.., .... ,~X ~0, 907 S73 1038 P, ,. Dally Report W~I! 112: Pioneer 1702t I~l;~t No: I; Screen Skil; Shei~r flo 1: -~hd~er No 2: Ihil#f No 3: Sh&k~ No 4: ' 50 §0 Ocean EnerW .. logistics IMarm~lon,, i . Bulk Mal~lal. ConSUmlo4:lofl and Inventory: Pipe Al: oIp ~ 4,5 125 i iiii , i1! · ,llll .... Sky Co~tdlU~n: ~ Air Temperature: ~5,o ;leg F Wind I~f: / Gra~f~ Ti,mm £ 4,$6H &a#ty Inf~lnatlon ~, , ...... .. lest Tirol ~ldmntm: 0 hy~ Since L?A: 5 cmUng 9' ,J O~P 'OH gzIC'~C:'Sz{~ ..',..~NI}t,,l~l I',i~':130 I,,iYE:g: ...' GE.E,'I: "~ ' 5,1-1d 212099 ?, 9 Mud Report Well ID: PionNr ii ii W~II Nlme: Plone~' Unit I~1702-11DA ii . . .i · il i iiii Ocean Energy Date/Time: Oa-Aug-9~) 23::}0 Engineer: Ed Elutt~ L~catien: PIT galld~ ~: ~ntple Depth: 21~ fl Water %: Mud Type: SPUD oll %: I:~rmlly: 8.g5 lb/gal ~&nd %: 2,5 Fennel VII: 210.0 ~eC~clt Laaw O.~. %: 2,0 PV: 50 cl~ High G.S. yp: 60 Ibs/t 00~¢t i.¢M ~: Gill o t0~: 2~. MuO AIl~llnl~ Pm: 0 t0mirtl: 44 F#~rM~ Alkadlnity 30mini: 44 Ftl t Alkall ty Mr: Mud Temp In: 78,0 dog F Cai;lorn: Mud Timi~ Out: 78.o ~leg .; ~hlorldet: FIIII'~I~: 12.4 Cld¢lum Chloride: 0 HTHP Flltrlte: 0,0 C03; 0 C~ke: 2~0 E~4c. 8lability; Mud pH: 9 CEC: ~7.5 Filtrate pH: e Llml Content: 0 OiIM~Mr RltiO: o / ~ A~tive Vol: Resewe VOl: 0,,0 bbl~ DUel to 18a', TOH to r~alr prop. TIH to t3ottom. Oonne~tions tight wi~ flU. In~e~ ViS. Gand Incm~l~, Ce,tdfuged one ~ah mud M~ Into a~ive, ¢omnlelIM: Pmt~cL' 4:9;3 4:24 FAX NO, Daily Report Well ID: Plorp~r 171)21S!:1A I~port No: 4 , I i ¥ i i ii 1,, O~ean Energy Wall Name: Pioneer UM t'I70~I,4IDA Riport for 2~:00 or,JiM Tlwldd E 4.SEH I.~st Time Aeetdoflt~: 0 O~ Sinai L?A: 4 ~: Grown~mefla Glto~k Sky Condition: Air TomMratur.: Wind , , · .... Wamther ........ ~r Visibility: C)~,O ~ag F ~', P~uro: 01 Wind ~usb: i , Dally Report Well ID: plorNmr 17021 Report ldo: 4 ! _, · .... =. --- , _ Drifting Parlmi~Mi, RaP WOG RPM 21B ~5 ~.9 ~ 90 'l~O . i ~ ~= ___ ''- ~._ . 3B000 PtOK Up: 38000 Ocean Ener Well Name: Pioneer Unit $1702.1 RII;~1 l~r 24:00 hll Oa~l. ug.II - . i i ..... i i Jl .... -- . Avg M~ A~ M~ iiii i i. ,,, 8~k ~: 3B~O Ne Run Maim MOdS Madg · ~, ,.. ' .... I L____. II ii . I:lept~ From AYO --. Blt lntarmition_~ ...... - .... , -Mud ~ Informl~on :-. L ~ j ~ T~ ' M ' I MB ~t ~h oonn~ ~ip ~p, I. Ithoh~g¥: OI.c~ai till 2 3! 1 016 17~ Uth,cdogy: top of tyonek 4GO ~ah) ~ 618-26 w. 311 bbs 630-640 wi 267 biag, e)09~'/2 41 blc~, .............. Rig Infm'matlo~ ........ -- , ..... Rig Nlme: CHP Eneroy RKB El~vatlmt: 2?5 It Equipment ~oblems pump il worn aul, will replKe the ~mp ah t~ nip~e up f~f luffS,, mg I~e ~, N~ w~der to p~ en heMrail~ a~ ~f~ cheine iR numeroun generally ~ ~ o~aslonal w~ B~t fr~ rain. ~u~e ~ $~ s~ an ed~ ~ loc Top MHSdIe Bottmn Equipment U~lgg: 110 110 ~11~: ~n~ffu~ No 2: Bulk ~lab C~tum~ ~ I~n~: 15 SoliCit Remova~ Used Thll RM:~Iv~ Thle Report Period RII)(X'I Pm'led Invdm~r'y' Barite: 0 0 0 6111~: 0 0 0 Geraint: 0 0 0 Fuel: O 0 0 Fm~t Weler; 0 O 0 Drift Watar: 0 0 0 Tru4~BmM Status: 6 ',=1 ;-:~' ' OH !g3:D~JF 0'.~.321 /.,.DW~t..4:I~ ' t..LH. 3DO HW~:E: :,-' ~,6 T ".:. ' ~I-IW FAX ~0, Dally Report IN~|i ID; Pianear ~?021SDA Report No: 4 Gperet=~: ~rl~ Hrs: ~monnml: O~at~: Plmnn~ O~~m: T~ipumh~: ~ ,, ~ --~. . 5:30 9:30 4,00 g:30 11:00 1,50 CIRC 11:00 13:00 2.00 DRILL 13:00 13:30 0.50 13:30 ~4:00 0,50 14:~ 18:00 4.00 DRILL 18:00 19:00 1,0~ ClRC Ig:OD 20;30 I ~0 20:30 21:30 1.00 ~H 21:30 23:D0 1,~ CIRC 23:0~ 0:~ 1~00 TOH Oo,~n EnerGy CHP Energy 29.dtd.l~ 3 On Lr~,atlolt.: 4 875 16 13.5 2 Contraotor: 12 Ocean Energy Well Name: PionNr Unit ~1702-leDA Reportfor,~4:0O Itm O~ug4~ m mi ,= , m _ --_ .... ~lm F~: PIo~ Uni~ T~ ~all ~b: $192,117 T=~I Daily ~o~/~; Mud ~tm: Tobl Vertlmd DeMIt: $?S Holm MW: 4~? Average ROP: 3:~ ~ 1;.37~ iii 35 Lair BOP Tm: 01-AU0-~ SMulee: 5 Other: 0 Tc4,iI: 1~ pooh to run zurfice oKI, Running 8 5/8 J-$.~ rotc ~ rcl ~. 0500 i~r. t~-~ run 9 ~8 o~g cat marne, nu boFi MI~, ~Niu~t~n Dennis ~kerman Dou~ We~on tight ~.n. mine ~n and ~r hole 2~8 · 307 aB fi, 25.4, bU~ ~ mak~ m~h ~mo~ 2~ R t~ ~g ~r and d.~n ~mnifer t~nk 438 - 523 85 ff 42,S f~ top or ~=nek 490 ]u~ rig dr dr & ~n~ to run ~oh m m ~g, ~O ~dem~, ~URV~ 2 DEG ~ 0~, MAY BE A U~LE SUSPECT ~ TOTCO H~ NO FEATHERS AND iNSTRUMENT WAS DROPPED, ...... Cemm~M ............. drille0 surface w/o hole p;oblems., '.itl run but~n Mt on ~urficm from no~ on i~d~cl of mill ~oath. ....................... M~I IMmmation ....... - Mnilty VI~ Flit Cake PV YP pH SoiidnWMer Oii 81nd Chlorlclm t~s 1Om 34)m 03-Aug 23:30 mt Del~h e?~ g.?o 60 t0 2 10 24 8. S tci.2 Bg.B 0 :3 gOO 7 ............ - ........ Il, Iud Con,~Um~b, le Items -- - . .... Item Des~rlMion Qty. Oo~t lie ~ipllon engineer - I man I O00 gel - 100~ bag GM~x · 2~ bag 2 ~ Tamp I~ Out 16 25 84.0 ~.o :- ._ Oty, cast 10 128 LDO ::PAK. S~ i-X FAX XO. 855 31 212099 -. C, lmad ,hmalm, ColMmd. ~l~ MORNING REPORT DATt~ &~l~ COMPANY & WELL OCEAN £NEK(]Y P,£$OU?,Ci~_ ]NC,_, DE~Jt ?ODAY 2tS Fr, YEiTEILgAYS DEFTH / ~- ~, FT/14 H~ ~ FT_, .......... F0PJClA~ON NOW DR/LL~G IN O~isl $OItMA~ON TOPS NtA PEO~ECTI~D FOI~4~T~ON 'I'O~S ~ACKGP~OUND GA~ 0.2 U. DOW1~I TIME OAS FLOP,,., CUT, O~ :STAIN N/A ..... m mm -- -- ' -- _ CK ElSt-.,' OH S331qCtOSSbt ,..L.,9~Skt3 t'.,Ib..J2:',,:: 66~ 7 ' ? ' 5',I-IU 2-99 8:29 P~I L}IOC PAl{SE '-)~ FAX BIO, Operations Activity Summary Well ID: Pioneer t?Ut~DA Well Nlme: plonur Unit f/tTO2-tSDA Ocean Energy 02.xug.$ 12,3o 12.~ ~2 REPR t0,~ ~ERV o,$ DRILL O,5 REFR 02' d ~3E:t:, *,:.'.,~,1 '.=T:13Nr'loD':l~ .x.g,~':l,.J3 I..l~3D,'~' t...lld'D~: .A 66E-., T. '?. ' I.¥1¥ Daily Report Well ID: Pioneer t?0215DA Report No: 3 Ocean Energy Well Name~ Pioneer Unit ~1702-15DA Report for 24:00 hm 02-Aug~q9 No Run Make Model Diem 1 I STC MS[~$H 12.250 Hole Made 177 Avg 0 0epth From To 12 2t8 Lithology: Bit Iriformaflor~ R.O.P. W.O,R. R.P,M. Torque Mud Pump Hm Avg Mex Avg Max Avg Max Avg Wt Ftow Pre~ ~3,5 20,8 1(] 15 60 86 2,6(3 321 400 Mud Log Information Gas Gas Drilling Pore Max at Depth Connect. Tdp Exp. Pres Rig Information Rig Name; CHF Energy RKB Elevation: Solids Control information ~0reerl ~IZ~; TOp ~j.d. dle Bottom Equipment Usage: Hr=, Shaker No I; §0 $0 50 Desender: Shaker No 2: ~ t 0 1 !0 Deqtilter~ 5~haker Ne 3: Degasser: Shaker No 4: Centrifuge Ne 1~ C;entrtfuge No 2; LogtstiGs Information ....... Bulk Materials Consumption and Inventory: Used This Re~eived This Repor~ Period Report Period Inventory Barite: dl O 0 Gels: 0 0 0 Cement: 0 0 0 Fuel: [3 0 0 Fresh Water: o o 0 Drill Water: 0 0 0 Truck/Boat Status: 24 276 ft $olid~ Rem0vsl $olKis Removal Drill Pipe At Location: DP Size Joints Weight 4,5 125 First Aid: 0 Medical: 0 Accident Desoril0tlon; MeetlngaJDrill$ Time Description ~ BOP Test Sky Condition; clear Air Temperature: 56.0 Wind SpeedlDir; 01 Gmcle Thread E 4.§EH .... Safety Information Lost Time Accidents: 0 Days Since LTA: L_J Ctownamatlc Check Weather, Visibility; Bar. Pressure.' Wind Gusts: 25 Prlrged: 9:54 03-Aug-gg P~o2 Daily Report Well ID: PioneertT0215DA Report No: 3 Ocean Energy Well Name: Pioneer Unit #1702-15DA Report for 24:00 hm 02.Aug-99 Operator:. Ocean Energy AFE Nos: DWIg01 - $372,387 Rig Name; CHP Energy Spud Date: ,?.9*J ul.99 Days: Since Spud: 2 On Lo~aflon: 3 Mea=umd Depth: 16 Prevleus Report Depth: 16 Drill Hm: t7.0 Leaf. Casing: Next; Pemonnet: Operator: 3 Contractor: 12 Current Operations.' Plannea Ope~tlon=: Toolpustmr: Well tt Bupewiso From To Elapsed Code 0:00 6:30 6..50 DRILL 6:30 8:00 1.50 SERV 8:00 11:30 3,$0 DRILL 11=30 12:00 0..",0 REPR 12:00 12:30 0..~0 SERV t2:,~0 '17:00 4.50 DRILL 17:00 ~.I:30 4.~i0 REPR 21'..30 0:00 2.50 DRILL Fielct: Pianesr Unit Total Well Cost.: Total Dally Costs: $23,B35 Mud Costs: $0 Total; $5,C64 Tot,~t Vertical Depth: 16 Hole Made: Average ROP: 13.375 at 35 Last BOP Test: 01-Aug-gg 8ervioe: 6 Other= 0 Total: 21 ddg ahead to td of surface hole Mike McNaughton Denni Doug Walt0 Dpem~ons Summary ..... Ot~emfions Deaoflpflon 12~8 35 fl, .B3 fp~. Ve~ ~ough tic,ten kelly he~e, came loose due ~ rough ddJ[i~g 4~.112 ~ ~ 18.2 ~h, stol rough right angle d~ive ~ts sheared, replace ~ iu~ a~d ~eck bolts on dg and a~hten same 112 - 188 ~ fl ~6,8 f~h po=-o~ cn pump ~affe~, p~h, mplec~ pop-off, wo~ on t~nsfe~ pump. t~8-215 3g ~ 12 f~h tn~ll~ burn bit end sm=~sd o[~t , Commen~ , Non,Prod the drilling is much smoother -,in~e installed button bit. All seems to be going OK now, The a minimum now. , Mud Infermation % Gels Tamp YP pH Solids Water Oil Sar~d Chloride 10a 10m 30m ~n out Density Vis Flit Cake PV 02-Aug 22:00 at Depth 63 8.a0 1~0 t2.8 1 3O From To 12 21~ ROP Avg Max 12.0 5O Off Etotl=m Rotate: 9 2 9B 0 D.25 900 36 ~4 Drilling Parametem , WOE RPM To~ue Row Avg Usx Avg M~ Avg ~x Avg Max PS! 10 65 ~0 ~0 MIs=ell=neoua Drilling Pamme~m Pl~k Up; Slack Off: ~ W~ar Bu~hlng InsUlted Hook Loads (lbs): Page I Daily Report Well ID: Pioneer 170215DA Report No: 2 Ocean Energy Well Name: Pioneer Unit #1702-15DA Report for 24:00 hfs 01-Aug.99 Operator: Ocean Energy AFE Nos: DWIg01. $372,387 R~g Name; CHP Energy ~pud D~: 2g~u~9~ Days: Since Spud: 1 On Location: 2 Measured Depth: D~II Hm: 0.5 Last Casing= Ne~: ~monneh Ope~tor: 3 Contm~ Currant O~rafions: dflili~g ah~a~ in gravel Planned Ope~tions: dri to To~lpua~er: Mike M;Naughto~ From To Eimpsed Code 0;00 12:00 12,00 REPR 12:00 12:30 0,50 BOPOT 12:30 2:~:00 10,50 23:00 2:3:30 0.50 DRILL 25:313 0=00 0.50 REPR Density Vis Flit Cake PV 01-Aug 23:59 at Depth 0 8.6n 165 2 35 Item Description engineer- I man ROP From To Avg Max 11 16 10,0 IG.0 i Hook Loads (Ibe): Off Bottom Rotate: Depth From To Avg 11 16 0 Llthology: Field: Pioneer Unit Total Well Costs: $241,0~4 Total Daily Costs: ~18,$24 Mud Co~: ($276) Total: $8,~4 Torsi Vertical Depth: Hole Made: Average ROP: 13.375 at 35 Last BOP Test: Ol-Aug-~ Service; 7 Other: 0 Total', 2?.. Doug W !ton Opel~tlom, 8ummar~ --... .... Operations Description a¢¢umula:or not wo~g prop~r~y, no n~gen ~n fun~on te~t dlve~r, :~t ~ccumulator system move desander to d~ing shaker, insa~l ~ll-up line ~ 1t~16, 5~, ~ hr, spud 23~ hm change pa~ki~ ~n m~ transit pump Mud Info.etlon % Gels YP pH Solids Wa~r Oil Sand Chlodde 10s 10m 30m Non-Prod X Temp In Out 46 9.5 0,02 0.98 0 0 9o0 20 38 Mud Comumabls Items Q~, Cost Item Description t 800 Credit- Drilling Parameters WOB RPM Torque Av~ Max Avg Max Avg MaX 3 3 40 40 Mis=ellaneou$ Drilling Parameters Pick Up: Casing: ,--- MUd Log Information .. Gas Max at Depth Connect. TrlD Qty. Cost I ~875 Flow Avg Max 32 t 321 I gO $1aok Off: Wear ~ushlng Installed Rotate Hra Trip Hra 0..5 , ., Drilling Pore Exp. Pres Page t '-gl; ' =1 O~CP '01'4 ~23DXl13C)S':I~I ...... ,.~N~F.J':I t..]ld3S,'3 L.I!5'_-D. A2: ....' G~,6,'[: '? ' ~,1-1¥ Daily Report Well ID.' Pioneer Report No: 2 , Rig Name: CHP Energy Equipment Problems: , ,, Screen Sizes: Top Shaker No I' 50 Shaker No 2; 1i0 Shaker No Shaker No 4: Ocean Energy Well Name: Pioneer Unit ~702-tSDA Report for 24:00 hm 01-Aug-99 .. , Rig I~orrnation RKO Elevation; 27B ~ a¢~lulator was not working properly, float had goten tluJd al:~(Tve it ~o it would not take a nitrogen charge, Bled off 25 gals fluid and was able to get I:rechar..qe to 10g0 psi. Changeci out packing m mu:~ ~an. sfer pump. $olld$ Control Information Middle BoLtom 110 Equtpmant Usage; Desander, Desllter:. Degasser: Cen~fuge No Centrifuge No Solids RemoYat Solids Removal Inventory 0 0 0 0 0 0 -- i_ Bill Bulk Materiat~ ConsumptiOn and Inventory: Used This Re~;eive¢ This Report Period Report Perlad Barite; 0 ~ Gels: 0 0 Cement.= 0 0 Fuel: 0 0 Fresh Water. 0 0 Drill Water: 0 0 Truck/eo~t Status: Drill Pipe At I.~cation*. DP Size Joints Weight 4,5 125 16,6 RI'at Aid: 0 Medical: 0 Accident Description: MeeflngstDrJile Time Deso.~ption I~, SOP Te~t ,. 8~ Conaltlon: ctear Air Tempeeature: 65.0 Wind $1~eedlDir: 2 / -- P~ted: g:55 03..Aug..~g dog F G~ade Thma~l E 4.$EH Safety Information Lost Time Aoclder~ts: Days ~qlnce LTA; 2 _, Cr0wnamatie Check Weather .. visibility: E~ar. Pressure: Wind Gusts: t5 P~e 2 4:20 :I>~ 0C, EA~-E~EGRY,,A..~.. ..... =._F_A..X NO_: .!07 ,~,~ 1{3~8 __. J MOI~NING REPORT DE?TH TODAY 6'~$ FI', 3'ESTI:P, DAYS DEPTfi 2t~ FF. --_ FORMATION NOWDR.tLLJ~G I"N ...C~..~ (~m~ FORMATION TOPS BACKOKOUND OA.~ 0-2 u, C',ONNECTION OAS TRIP Gi~,S NIA AT DOWn, TI'ME GAS CIA~ 5II0W$ A,'~D DIIIr,T.II~G BIL~MCS_. .......... . .......... ._9~ff!~-- u_~,~,=~ ~ ~x ..~.~*s----&~ .... l .... -.%. ...................... FLOR,, C~,'I', OR STAI~ N/A ........................ . .......................................................... Eli'S & TI~FS WOB lo, lJ $~ton~. The Erst c~l 1-,sd er[cotmt~ed ~ 618'fl. with eKociJi~ct 9~s or,ti m'tit~. . ........................ Daily Report Well ID: Pioneer '170215DA Report No: '1 , Ocean Energy Well Name: Pioneer Unit ~?02-~ 8DA Report for 24:00 hm 51-Jul-99 Op~-ato~. AFE l~s: Rig N~me.' Spud Date: Days: ~ln~ SPud: Me.Urn= Depth: Pr~io~ Rapo~ Dep~: Drill Last ~lng: Pemonneh Ocean Energy DWIg01 - $372,387 CHP Energy 29-JuFg@ 0 On Loc-'~on: 1 '11 Cont~ctor: O. Next: 11 Field: Pioneer Lrnlt Total Well Coate: $22Z,540 Total Daily Costs: S22.~,540 Mud Cost~: $5,340 To~h $$,340 To,al Vertica~ Depth: 11 Hole Made: 11 Average ROP: 13.375 at 35 Last BOP Toot: Service: 6 Other; 0 Total: 20 Current OpsmUnns: Planned Operatiorm: Toolpus~;r: Well"'ite ~Supervlsora: Fmr~ To Elap;ed 0:00 0:00 24.00 rig aeculmultor hoc working properly, having to n~paJr or get new closing un!t. Down unflJ oan ~et up to snuff, Mike Mchiaugh~on Dennis A~kennan Doug Walton Operation"' 8umma~ . ,, Code Operations Deacrlptlen NUIND W~d on 13 5/$ stardng I~eaO, nu 13 $/8 SM diverter assembly wi 10" blooie line, build ~low line & bell nipple. Change desan~ler t¢ over drying shaker. Item DescriptJon gel - engineer - Rig Name: SGmen Size.,: Shaker No ~: Sl~al~e~ No 2: Shaker Ne 3: Shaker No 4: iii1__ CHP Energy Top 110 Middb 50 110 , Mud Consumable Items , I03 5 Coat Eom Description 2,257 soda ash- 3,000 Rig Information RKB Elevation: Qty, 276 ff coat Solld~ Control Infom~aflen Bottom Equipment Uaege: Dea~noer: Desilter: De,asset: Centrifuge No ~; Centrifuge No ~= 0 Solids Removal $olicls Removal Page Daily Report Well ID: Pioneer 4702t6DA Report No: 1 Ocean Energy Well Name: Pioneer Unit #1702.15DA Report far 24:00 hfs 3t-Jul-99 .,, Logiatice Information ~ . rauJk IVlateriats C~umptlon anti Inventory: Used ThL~ Reeeived This Repo~ Pe~od Eaport Period Inven{ory Barite: 0 0 0 Gels: O 0 0 Cement: 0 0 0 Fuel: 0 0 0 Fresh Wate~ 0 0 0 Drill Wafer, 0 0 0 Truck/Boat Status: Drill Pipe At Location.' DP Size Joints Weight 4,6 125 16,5 First Aid: 0 Macli=~l: 0 Accident Deserllatlon: MeeflngslDHIIs Time De.~crlpflon ~ mop Sky Cenalition; de;r, Air Temperature: 65.0 deg F Wind 51~eedJDir; 0 / Grade Thread ~ 4.SEH Safety Information Lost Time Accidents; 0 Days Since LTA: [] Orownamalic Check Weathe? Visibility: Bar, Presaure: Willd Guer$: Printed; g:53 Pa~e .e A_ '[ ' ,d Cd.~P 'ON S-:ID~II-OS3~. ,,',,gEt'q.l',l} FIU3,.90 HU'3£ :,) GES61: "_: ' MEMORANDUM TO: State of Alaska /~j~,~ Oil and Gas Conservation Commission Robert Christensoh ~/" DATE: August 8, 1999 Chairman THRU: Blair Wondzeli, .~,.~e~ P. I. Supervisor FROM: Lawrence M V~a~e SUBJECT: Petroleum Inspector FILE NO: a99ghhgf. DOC BOP Test CH&P 19 Pioneer 1702-15DA PTD 99-64 Auaust 6,1999: I traveled to the Pioneer Unit well to witness a BOP test on CH&P rig 19. I arrived on location at 7 am and they were finished nippling up by noon. We started by inadvertently cuffing the O-ring on the test plug which was replaced. After that we found a bullplug leak on the stack. We found the hydril leaking, we also had a leak under the floor valve. We couldn't get a test on any of the stack valves and found contaminated fluid in the hydraulic reservoir that supplied the BOPs. The hydraulic filters were clean and we deduced that there was some serious problems with the blind and pipe rams. I left the location, leaving the drill crew to overhaul the stack. Auaust 8. 1999 i returned to the rig to test BOPs. The crew had found seals out of the pipe and blind rams. We tested the pipe, blinds, HCR, choke manifold and kill line valves. Everything tested o.k. except for the hydril which was found to be a divert valve. It would not pass the pressure test. They then decided to replace the hydril with the rotating head as ! left location. August 9, 1999 I traveled back to Pioneer Unit well and looked at their rotating head assembly. Installing this precipitated installing a new line to the degasser and installing a block valve in the flow line off the bell nipple. The installation looked acceptable to me and ! told the company man, Dennis Ackerman, that, as far as ! was concerned, he could continue with the drilling program. SU .MMARY.: Witnessed the BOP test on CHP rig 19, three days, 28 hours, three failures. Attachments: a99hgfg.xls qC; STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: x Workover: ,, , Drlg Contractor: CH&P Rig No. Operator: Ocean Energy Resources Well Name: Pioneer 1702-15DA Casing Size: 9 5/8 Set (~ 675 Test: Initial X Weekly Other 19 PTD # , , Rep.: Rig Rep.: Location: Sec. gg-64 DATE: &'6/99 Rig Ph.# 1-877-87~-1037 Dennis Ackermann Mike McNa. ughton 15 T. f7N R. 2W Meridian'-' Seward , ~ Test' Pressures 200/2000 I'MISC. INSPECTIONS: Location Gen.: ok Housekeeping: ' "o~ (Gan) . PTD On Location X' Standing Order posted Test Well Sign X Drl. Rig X Hazard Sec. FLOOR SAFETY VALVES: Quan. Pressure P/F Lower Kelly / IBOP 200/2000 Ball Type f".' 200/2000 ~ lnside BOP .1 I. 200/2000 i i' BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. PtF 200/2000 .... '~" '2do/2boo' ' ' 1' '2~0/2000 f 200/2000 ' '~ '20'o/2bOd' · ,,, MUD SYSTEM: Visual Tdp Tank . X .Pit Level Indicators X Flow Indicator X Math Gas Detector X" H2S Gas Detector X Alarm X X X- Test CHOKE MANIFOLD: Pressure PIF No. Vaives 3 ! 200/2000 I P No. Flanges .",~i.' , 2.00./'2000 -~ Manual Chokes . Functioned P Hydraulic Chokes Functioned ACCUMULATOR SYSTEM: System Pressure 1,500 Pressure After Closure ..... j,~/~0' 200 psi Attained After Closure ~ minutes f5 sec. System Pressure Attained minutes '-~' sec. Blind Switch Covers: Master:.. ' Remote: Nitgn. Btl's: 2300-2325-2350 Psig. f,:,- .................... ........ : ., : : ; ~':; · ;, · ; ., ;. : . .: · _~ .... : .~ ...... '.' ....... '-~-'-'-'-'. :'-'.'..'-'.'.' ......... '-' ....... '-' - ' ;- ........ "' .......... ~' "'L ' ........ Number of Failures: f ,Test Time: fT.O Hours. Number of valves tested 8 Repair or Replacement of Failed Equipment will be made withi~ ' days. Notify the Inspector and follow with ~tten or Faxed verification to the AOGCC Commission Office at:" J~ax NO,' 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279.1433 I J I ! III I I II II I! I. I I I. I ! .I I II I II I II IIIII III I .I III I I REMARKS: . ~ - _ . il , __ . 1, 1, ~ Distribution: odg-Well File c - Oper./Rig c - Database c - Trip Rpt File c - Inspector $~'AT'~'WI'TNES~;-REQUIREb~ YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: FI-O21L (Rev.12/94) aggghfgf.xls JUL--29--c~9 04 : 38 C~R PIPE AND STEEL 90745668?5 C & R Pipe and Steel, Inc. P.I) I FACSIMILE TRANSMISSION To: Blair Wondzell Company: State of Alaska Oil & Gas Fax #: 276-7542 From: Dennis Wilfer Date: July 29, 1999 Time: 4:35 PM 2 _ PAGE(8) TO FOLLOW Accompanying 2 pages from Maverick. My apologies on the yield strength which is slightly less than I previously stated. However tensile is higher. hope this information is helpful. Best regards, RECEIVer) 'JUL ~90 1999 7Alaska 0il & Gas ~.~..~. Anchorage P. O. Box 70743 Fairbanks, Alaska 99707 (907) 456-8386 Fax (907) 456-6875 401 East Van Horn Road s.~.s~rds to be Identified as CP $0 casing, P.02 YId,.I RECEIVED JUL ,3 0 1999 R/aska Oil & Gas Cons. Commission Anchorage ItS APl .qCT 8amc aa Alq ~ exert O.D. mlc~,a~ + t %, -~% CexqpU~o4 I~atmed ~ wl~ oo~ ~r~lc • July 14, 1999 Ms. Wendy Mahan Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: Pioneer Unit # 1702 -15DA WDW Section 15- T17N -R2W Matanuska - Susitna Borough Injection Disposal Application "' - ::: � 2 Dear Ms. Mahan; At this time we are requesting to keep confidential the drilling prognosis portion of the application for injection on the subject well. All of the other portions of the application can be displayed for public scrutiny. 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 1 ' s 1999 , , :ferns. Com ""4 &011 Ocean Energy Resources, Inc. Amoco Building 1670 Broadway, Suite 2800 Denver, Colorado 80202 (303) 308 -8500 Fax: (303) 308 -8510 `rHo • • PIONEER MATANUSKA- SUSITNA BOROUGH, ALASKA DRILLING PROGNOSIS "TIGHT HOLE" WELL: # 1702 -15DA WDW (6/29/99) FIELD: Pioneer Unit SURFACE LOCATION: Section 15 -T17N, R2W, Matanuska - Susitna Borough, Alaska 1354' FSL & 527' FEL ELEVATIONS: GL: 265' & KB: 276' ESTIMATED TD: 4,100' MD PRIMARY OBJECTIVE: Tyonek Formation ;icy e • • PIONEER MATANUSKA- SUSITNA BOROUGH, ALASKA DRILLING PROGRAM LOCATION: The drilling pits will be self contained units. Have water tested by both the mud engineer and BJ Services engineer prior to spudding for any problems. Locate an emergency response trailer in an accessible area on the drilling location upwind from the wellhead. Set and cement conductor (minimum of 12 -3/4" drift ID) to +/ -35 feet. 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 (ml) No Control pH No Control PV (cp) 15 to 20 YP (lbs/100 ft 15 to 25 Undissolved Solids ( %) 0 to 5 SURFACE 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 ring. 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 onto bottom joint. Depth Interval Casing Burst/SF Collapse/SF Tension/SF 0' - 700' 9 -5/8" 36#/ft J -55 STC 3,520 psi/8.80 2,020 psi/6.313 394 Mlbs/15.63 (J) • PIONEER MATANUSKA - SUSITNA BOROUGH, ALASKA SURFACE HOLE: Surface to700' (continued) SURFACE 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 gal/bbl SAPP -400 sxs "G" cmt + 2.0 % CaC1 and 1 gal/100 sx FP -6L - Displace with fresh water. Cement Properties "G" Slurry Weight (# /Gal) 15.80 Slurry Yield (Cubic - Ft/Sx) 1.16 Mix Water Required (gal/sx) 5.00 Estimated Pump Time (HH:MM) 2:30 Compressive Strength: 24.0 Hr. @ 100 Deg. F (psi) 4,000 NOTE: Surface casing must be cemented to surface. If necessary, I" to surface with Class "G" + 2% CaC12. WELLHEAD and BLOWOUT PREVENTION: Cut off 9 -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. BOP equipment will consist of a 3000 psi, double ram preventor with blind rams, as well as an annular preventor. After installation of BOP's, blind rams will be closed, and BOP & Manifold will be pressure tested to 2500 psi. After testing of the blind rams & Manifold, the Pipe Rams will be pressure tested to 2500 psi with a joint of drill pipe. Release the pipe rams after testing, and close the annular preventor for a test to 2000 psi. Record all test results on daily drilling report. PIONEER MAINUSKA- SUSITNA BOROR-H, ALASKA PRODUCTION HOLE: 700' TO 4,100' After successful testing of BOP equipment to 2500 psi, test the surface casing shoe to 1500 psi then drill out of the 9 -5/8" surface casing with an 8 -3/4" bit using surface hole mud. Drill and perform leak -off test with -in 10 feet of new formation (or an equivalent mud weight test @ 11 ppg). Important Notes during Drilling of Production Hole: 1. Always establish circulation at the surface casing shoe while tripping back in the hole. 2. Always wash and ream the last two (2) joints of drill pipe to bottom while tripping back to bottom 3. Always slow trip speed down to no more than 60 seconds per stand below 2500 ft 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 on Location. PRODUCTION 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, viscosity, 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 OERI representative on location. Be prepared for potential gas kicks or water flows when drilling below 1,800'. Depth: 700' to TD Build production hole mud from surface hole mud Weight (ppg) 10.0 to 11.5 Viscosity (sec) 75 or less API Filtrate (ml) 10 or less HTHP (cc) N/C PV (cp) 30 to 35 YP (lbs /100 ft 20 to 25 Solids (lgs) 13 to 24% PIONEER MATNUSKA- SUSITNA BOROAH, ALASKA PRODUCTION HOLE: 700' TO 4,100' (Continued) Logging Program: The following log program will be ran as a minimum. DIL /SFL -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 be faxed to the Denver office as soon as the field prints are available. Coring Cores may be cut through the Tyonek formation on the second of third well across the Tyonek P Coal or the Tyonek BLT Coal to allow determination of reservoir properties. Geology: #1702 -15DA GL = 265' KB = 276' Formation Depth / SS Datum Glacial Gravel Surface /(265') Tyonek 510' /( -234') (From KB) Tyonek B Coal 1,030'/( -754') Tyonek B Sand 1,300'/(- 1,024') Tyonek C Sand 1,765'/( - 1,489') Tyonek C Coal 2,250'/(- 1,974') Tyonek P Coal 3,175'/(- 2,899') Tyonek BLT Sand 3,420'/(- 3,144') Tyonek BLT Coal 3,600'/(- 3,324') Estimated TD 4,100'/(- 3,824 ") 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. PRODUCTION CASING & CEMENTING 7" casing will be ran to TD, and we are planning on cementing this string with a three stage cement design. Stage tools will be run in the 7" casing at +1- 2,700' and +1- 1,400'. BJ Services out of Kenai, AK will be pumping the cement job. Depth Interval Casing Burst/SF Collapse/SF Tension/SF 0' - 4,100' 7" 23 #/ft WC -50 LTC 4,000 psi/1.75 3,110 psi/1.36 287 Mlbs /3.75(J) PIONEER MA NUSKA - SUSITNA BOROOtH, ALASKA PRODUCTION HOLE: 700' TO 4,100' (Continued) PRODUCTION 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 run 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 to a planned TOC at surface. Cement Program -20 bbls Mud Clean II -1st 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 2 ° stage -10 bbls Mud Clean II -2nd Stage: 121 sxs "G" Cmt + 0.75% CaC1 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 of 4hrs WOC after 2nd stage before pumping 3rd stage -10 bbls Mud Clean II -3rd Stage: 113 sxs "G" Cmt + 1.00% CaC1 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 1st Stage 2nd Stage 3rd Stage Cement Properties Slurry Weight (# /Gall) 15.80 12.50 11.50 Slurry Yield (Cubic - Ft/Sx) 1.15 2.10 2.11 Mix Water Required (gal/sx) 4.95 11.96 11.98 Estimated Pump Time (HH:MM) 4:00 4:00 4:00 Compressive Strength: 24.0 Hr. @ 200 Deg. F (psi) 4,000 24.0 Hr. @ 165 Deg. F (psi) 575 24.0 Hr. @ 210 Deg. F (psi) 575 Note: Cement volumes are based on 30% excess. When caliper log is obtained, 1st 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 and set slips. ND BOPE & Make cut on 7" casing. Nipple up tubing head. PIONEER MA USKA- SUSITNA BOROH, ALASKA OEI Personnel Phone List Production Manager: Douglas Walton Office: (303) 308 - 8867 Fax #: (303) 308 - 8697 Home: (303) 721 - 1787 Mobile: (303) 898 - 6920 Drilling Manager: Chuck Wilson Office: (303) 308 - 8864 Fax #: (303) 308 - 8697 Home: (720) 283 - 0108 Mobile: (303) 748 - 3624 Engineer /Geologist: Robert Downey Office: (303) 308 - 8822 Fax #: (303) 308 - 8697 Home: (303) 850 - 0284 Mobile: (303) 807 - 5262 Foreman: Larry Curtis Office: (307) 746 - 4052 Fax #: (307) 746 - 4045 Home: (307) 746 - 2202 Mobile: (307) 680 - 9052 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-Susitna Borough Pioneer Unit # 1702-15DD Section 15-T17N-R2W Matanuska-Susima Borough Pioneer Unit #1702-14CC Section 14-T17N-R2W Matanuska-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 Anchorage, Ocean Energy Resources, Inc. Amoco Building 1670 Broadway, Suite 2800 Denver, Colorado 80202 (303) 308-8500 Fax: (303) 308-8510 1 a. Type of work Drill: X Re-Entry: 2. Name of Operator STATE OF ALASKA AND {GAS CONSERVATION CO( PERMIT TO DRILL Redrill: I lb. Type of well Deepen: I Service: Ocean Energy, Resources, Inc. 3. Address 1670 Broadway, Suite 2800, Denver, CO 80202-4826 4. Location of well at surface 527' FEL & 1354' FSL At top of productive interval 527' FEL & 1354' FSL At total depth 527' FEL & 1354' FSL Sec. 15-T17N-R2W 13. Distance to nearest well 12. Distance to nearest property line 527' feet 16. To be completed for deviated wells Kickoff depth: feet NA feet 18. Casing program size Maximum hole angle: IISSION Hole I Casing Specifications Weight I Grade I C°upling I Exploratory:/~' Stratigraphic Test: Developement Gas: X Single Zone: 5. Datum Elevation (DF or KB) GL: 265' KB: 276' feet 6. Property Designation ADL-374117 7. Unit or property Name Pioneer Unit ~-- 8. Well number ~ i 702,-15DA WDW 9. Approximate spud date Upon Approval 14. Number of acres in property 2721.06 10. Field and Pool Pioneer Unit Development Oil: Multiple Zone: 11. Type Bond (see 20 AAC 25.025) Number JZ-8072 Amount $200,000.00 15. Proposed depth (MD and TVD) 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) 4,100' feet Maximum surface I Settini Depth Top Bottom Length MDI I Tv. 1410 psig At total depth ('rVD) 1500 psig 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 I I I I I I I ;,';:xx 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet true vertical feet Plugs (measured) Effective depth: measured feet Junk (measured) true vertical feet Length Size measured True vertical depth RECEIVED: JUN 0 1999 Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Cemented Measured depth ORIGINAL ~asi~ 0il & 6as Co~. C0m~iss[~;~,, true vertical Aach0rage 20. Attachments: Filing fee: XX Property Plat: XX BOP Sketch: XX Diverter Sketch: NA Drilling program: Drilling fluid program: XX Time vs. depth plot: Refraction analysis: Seabed report: 20 AAC 25.050 requirements: 21. I herby certify that the foregoing is true and correct to the best of my knowledge: Signed: _.,~~ ~_'~~-~.,,...._~ ~.,-~~'~ Title: Regulatory Coordinator Commission Use Only Date: 6/28/99 Permit Number Condition's of approval Samples required: [ ] Yes Hydrogen sulfide measures [ ] Yes ~ No Required working pressure for BOPE ~2M; [ ] 3M; Other: ORIGINAL SIGNED BY Robert N. Christenson Approved by Form 10-401 Rev. 12-1-85 IAPI number I Approval date ,,,,~ See cover letter 50- 0(:3 ~'-' Z (::) (:3 ~' ~" I '7'" O~ ff"' ~ ~' for other requirements ~ No Mud Icg required: [ ] Yes '~ No Directional survey required [ ] Yes '~ No []5M; []10U; []15M Commissioner 20 AAC 25.005 by order of the Commission Date: Submit in triplicate Pioneer Unit #1702(-' ~DA WDW Proposed Water Disposal Well NE SE Section 15-T17N-R2W Matanuska-Susitna Borough, AK GL: 265' 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 with 455 sx IIGII' 4) Tubing:2-7/8"/6.5# / J-55 / EUE 8rd @ 50' above top perfs. 5) Packer @ 50' above top perfs. 6) Perforations Between 2,500' and 4,000' (estimated). 7) TD: 4,100' 6 J 7 i~3 CH&P RIG #19 Hydraulic Oil - 100 gal. Motor Oil - 200 gal. Gear Oil - 100 gal. 150 bbl. Brine Tank 4700 gal. Diesel fuel 285' bbl. Fresh Water Light Plant Dog House Brine for Hydromatic - 220 gal. ,,' Mud Pump Diesel Fuel 199 gal. Hydraulic Oil - 260 gal. Cat Walk Pipe Racks ,. ....... " .. Guylines - 60' back / 45' out from center ./lines ~ 60' front / 60' out from center Mud Pit 300 bbl. Rig Floor j/ 35 feet from center of well to reserve pit Reserve Pit STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: THE APPLICATION OF OCEAN ) ENERGY RESOURCES, INC. ("Ocean ) Energy") for disposal of Class II oil field ) wastes by underground injection in the ) Pioneer Unit # 1702-15DA WDW well. ) Disposal Injection Order No. 20 Well #1702-15DA WDW Pioneer Unit August 11, 1999 IT APPEARING THAT: By correspondence dated June 28, 1999, Ocean Energy requested authorization from the Alaska Oil and Gas Conservation Commission ("Commission") to dispose of Class II oil field waste fluids by underground injection into the Pioneer Unit #1702-15DA WDW well, located in Section 15, Township 17 North, Range 2 West, Seward Meridian. . The Commission published notice of oppommity for public hearing in the Anchorage Daily News on July 2, 1999. A second notice of opportunity for public hearing was published in the Anchorage Daily News and the Frontiersman on July 16, 1999. 3. The Commission did not receive any protest or a request for a public hearing. . The proposed disposal project requires an aquifer exemption under 20 AAC 25.440. The Commission issued Aquifer Exemption Order #5 on June 29, 1999, after receiving no objection from the U.S. Environmental Protection Agency. FINDINGS: o Ocean Energy is the operator of the Pioneer Unit. There are no other operators within a one-quarter mile radius of the proposed disposal injection well. Ocean Energy has notified the surface owners by certified mail of the proposed disposal project. . Aquifer Exemption Order #5 exempts those portions of aquifers underlying the Pioneer Unit in Sections 14, 15, 22 and 23, Township 17 North, Range 2 West, which are common to and correlate with the interval below 2,790 feet in the BLT No. 1 well. Disposal Injection Orde~, o. 20 August 11, 1999 Page 2 Ocean Energy proposes to conduct disposal injection within the proposed Pioneer Unit 1702-15DA WDW well in strata of the Tyonek Formation, which are common to and correlate'with the interval below 2,790' in the BLT No. 1 well. . The proposed disposal zone in the BLT #1 well is confined by over 700 feet of shale between the top of the disposal interval and the base of freshwater known to be used in the area. Similar confinement is anticipated at the proposed Pioneer Unit 1702-15DA WDW well location. o There are currently no other wells within one-quarter mile radius of the proposed Pioneer Unit 1702-15DA WDW well that penetrate the injection zone. Specific injection intervals will be identified after the Pioneer Unit 1702-15DA WDW well is drilled and logged. Ocean Energy will analyze produced water samples tbllowing completion of the well to confirm that the aquifers meet the requirements fbr exemption specified in 20 AAC 25.440. Copies of the water analysis will need to be submitted to the Commission for concurrence. , A cement bond log will be run and cement records evaluated to ensure that the #1702-15DA WDW well is cemented adequately to isolate the proposed disposal interval. Be The well will be completed with 133/8 inch conductor set at 35 feet MD, 9s/8 inch surface casing set at 700 feet MD and cemented to surface, and 7 inch production casing set at 4,100 feet MD and cemented back into the surface casing. o The well will be equipped with 27/8 inch tubing string and packer set 50 feet above the top of the perforations or the uppermost disposal interval, whichever is shallowest. 10. 11. Ocean Energy intends to utilize the Pioneer Unit 1702-15DA WDW well to dispose of fluids and drilling wastes from the coalbed methane test wells described in the "Pioneer Unit Plan of Operations" and the "Pioneer Unit-Vine Extension Plan of Operations." The waste stream will consist of produced formation water, drilling, completion and workover fluids, rig wash, drilling mud slurries, and other Class II fluids generated from drilling, production, workover and completion operations. Although initially predominantly produced water, constituent volumes may vary depending on drilling, workover, stimulation and maintenance activity. 12. Ocean Energy estimates that the maximum daily volume to be injected will be 2,000 barrels per day. 13. Ocean Energy estimates the average and maximum injection pressure will not exceed 900 psi. 14. Ocean Energy will conduct periodic surveillance of disposal operations through temperature surveys, pressure transient tests, step rate tests, thermal decay time Disposal Injection Order No. 20 August 11, 1999 Page 3 logs, disposal rate and pressure monitoring, mechanical integrity tests and tagging effective depth to determine fill buildup. 15. Reservoir surveillance techniques will also be used for tracking near wellbore fluid movement, estimating dimensions of disposal fracture or disposal storage volume and detecting changes in disposal zone characteristics. 16. Evaluation of operational performance data and reservoir surveillance data will aid in preventing fracturing of the confining zones. CONCLUSIONS: 1. The requirements of 20 AAC 25.252(c) have been met. , Those portions of aquifers underlying the Pioneer Unit in Sections 14, 15, 22 and 23, Township 17 North, Range 2 West, which are common to and correlate with the interval below 2,790 feet in the BLT No. 1 well, are exempt for Class II injection activities. , Waste fluids that are authorized for disposal in the Pioneer Unit 1702-15DA WDW well will consist exclusively of Class II waste generated from drilling, completion, workover and production operations. 4~ Permeable strata, which are common to and correlate with the portion of the Tyonek Formation below 2,790 feet in the BLT No. 1, are likely to be present in the Pioneer Unit 1702-15DA WDW well. These strata can reasonably be expected to contain the total volume of disposal fluids anticipated for this project. o Waste fluids will be contained within appropriate receiving intervals by confining lithologies, cement isolation of the wellbore and operating conditions. 6, Disposal injection operations in the Pioneer Unit 1702-15DA WDW well will be conducted at rates and pressures below those required to fracture the confining zones. , Periodic surveillance of disposal material placement, daily monitoring of operating parameters when in operation, and demonstration of mechanical integrity at least every two years will ensure the waste fluids are contained within the disposal interval. Changes in baseline data may be an indication that fluid is escaping beyond the designated confining zone. , The mechanical' integrity of the tubing, packer and production casing in the Pioneer Unit 1702-15DA WDW well must be demonstrated in accordance with 20 AAC 25.412 prior to commencing injection operations. . Disposal injection operations in the Pioneer Unit 1702-15DA WDW well will not cause waste, jeopardize correlative rights, or impair ultimate recovery. Disposal Injection Order ~,o. 20 August 11, 1999 Page 4 NOW, THEREFORE, IT IS ORDERED THAT: Rule 1 Authorized Injection Strata for Disposal. Class II oil field fluids may be injected in confbrmance with Alaska Administrative Code Title 20, Chapter 25, for disposal into Tyonek Formation strata that are common to and correlate with the interval below 2,790 feet in the BLT No. I well in the # 1702-15DA WDW well. Rule 2 Authorized Fluids This authorization is limited only to Class II fluids. The Commission must be notified immediately if any non-Class II fluids are injected into the well. Rule 3 Demonstration of Tubing/Casing Annulus Mechanical Integrity A schedule must be developed and coordinated with the Commission that ensures the tubing-casing annulus is pressure tested prior to initiating disposal and at least once every two years thereafter. The casing must be tested at a surface pressure of 1500 psi or 0.25 psi/ft multiplied by the true vertical depth of the packer, whichever is greater. The test pressure must show stabilizing pressure and may not decline more than 10 percent within 30 minutes. The Commission must be notified at least twenty-four (24) hours in advance to enable a representative to witness pressure tests. Rule 4 Wel! Integrity Failure Whenever disposal rates and/or operating pressure observations or pressure tests indicate pressure communication or leakage of any casing, tubing or packer, the operator must notify the Commission on the first working day fbllowing the observation, obtain Commission approval of a plan for corrective action and obtain Commission approval to continue injection. Rule 5 Surveillance Operating parameters including disposal rate, disposal pressure, annulus pressures and volume of fluids and solids pumped must be monitored and reported according to requirements of 20 AAC 25.432. An annual report evaluating the performance of the disposal operation and summary of surveillance activity and results must be submitted by' July 1 of each year. Rule 6 Administrative Action Upon request, the Commission may administratively revise and reissue this order or any of its rules upon proper showing that the change is based on sound engineering practices, will not allow waste fluids to escape from the disposal zone, and will not cause waste. i' Disposal Injection Order No. 20 August 11, 1999 Page 5 DONE at Anchoragel Alaska and dated August 1 1, 1999. Robert N.XC~'tll~stenson, P.E., Chairman David sioneF"- AS 31.05.080 provides that within 20 days after receipt of written notice of the entry of an o'~er, a person affected by it may file with the Commission an application for reheating. A request for rehearing must be received by 4:30 PM on the 23rd day fbllowing the date of the order, or next working day if a holiday or weekend, to be timely filed. The Commission shall grant or refuse the application in whole or in part within I0 days. The Commission can refuse an application by not acting on it within the 10-day period. An affected person has 30 days from the date the Commission refuses the application or mails (or otherwise distributes) an order upon rehearing, both being the final order of the Commission, to appeal the decision to Superior Court. Where a request for rehearing is denied by nonaction of the Commission, the 30-day period for appeal to Superior Court runs from the date on which the request is deemed denied (i.e., 10th day after the application for reheating was filed). SUPPLEMENTAL Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re: Pioneer Unit Disposal Injection Order Ocean Energy Resources, Inc. by letter dated June 28, 1999, has requested an order allowing the disposal of Class II fluids in the Pioneer Unit in the Matanuska- Susitna Valley in Southcentral Alaska. The requested order would allow disposal of oilfield wastes in the Pioneer Unit #1702-15DA WDW well located in Section 15, Township 17 North, Range 2 West, Seward Meridian. A person who may be harmed if the requested order is issued may file a written protest prior to 4:00 PM, August 2, 1999 with the Alaska Oil and Gas Conservation Commission, 3001 Porcupine Drive, Anchorage, Alaska 99501, and request a hearing on this matter. If a protest is timely filed a hearing on the matter will be held at the above address at 9:00 AM on August 17, 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. Copies of the application for disposal injection are available for inspection at the AOGCC office at the above address. This notice supersedes the notice published July 2, 1999 that would have provided an opportunity for public hearing on August 3, 1999. The August 3 date is withdrawn. If you re 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 at 793-1221 before August 11, 1999. Robert N. Christenson, P.E. Chairman Published July 16, 1999 ADN AO# 02014004 STATE OF ALASKA ~,. ~SKA 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 Notice is ereby given of a designation of operatorship for the oil and gas property described below: Legal description of property: See attached Exhibit Property Plat Attached ,-- Name and Address of Designated Operator: Ocean Energy Resources, Inc. 1001 Fannin, Suite 1600 Houston, Texas 77002 Effective date designation: July 1, 1999 AcceptanCesigned./c~/~'''°f ope~Tp~.~for the above-described property with all attendantDate responsibilitieSjU ]y 2 ,and1999obligations is hereby acknowledged. Name (printed). Hank Wood Title (printed) At torne¥- in-Fact The owner hereb)/certifies that the foregoing is true and correct. S'gned _LL,~..~ ~' /'"'" Name (printed) Kevin A. Tabler Date (.c,, Title (printed) Attorney-in-Fact Date Approved / ~ Form 10-411, Rev. 01-08-92 Date Submit in Duplicate JUL--29--99 12 .'~5 PM C~R I' PIPE AND STEEL 98745668?5 C & R Pipe and Steel, Inc. P.~I -044 FACSIMILE TRANSMISSION To; Blair Wondzell Company: State of Alaska Oil & Gas Fax #: 276-7542 From' Dennis Wilfer Date: July 29, 1999 Time: 12:35 PM 0 PAGE(S) TO FOLLOW Dennis Ackerman with Ocean Energy requested I send to you spec's on the CF-50 material. The physicals are similar to J-55 in that it exceeds 55,00C~ in yield strength and 75,000~ in tensile strength. The product was produced by Maverick Tubulars. If you require additional information you can contact me at the below number. RECEIVED dUL 29 1999 Alaska 0il & Gas UU.o. ~,ummlssion Anchorage P. O. Box 70743 Fairbanks, Alaska 99707 (907) 456-8386 Fax (907) 456-6875 401 East Van Horn Road JUL--29--99 04 :~9 PM C~R PIPE AMD STEEL P.O~ MA RICK A, me, rlca',~ Quality Mills MAVERICK PERFORMANCE PROPERTIES AND RECOMMENDED SETTING DEPTH LIMITATIONS CALL TOLL FREE: t-800.328-1777' FAX: $I 4.5~?-13'~ 6 7~'"-' :3~ ' ;'~7,0 '~ -'~0 11180 34~ q1050 30?- 7740 .......... :~'-~' '..!.%0_ N-BO ;' ~.. '" t11~ 3-48 ' 11370 397 TT~O . &~ ~:~J t0iO",'' N,~ 'fl~o 18700 4i8._ i--ft:B~ PUT-'F'~'J~. -~a,o ..... peq ~ ~/ ~ss4o BOa -'1~]~' .q~, 'mS~_ - ..... I .,~, ,, .... i., , .... --- -- :7-- 'ea~ ..... j" 44~ 1~ 6~40 ~'- .G6'b'"-~e,O,~' ~ ' 43~0 770~7" ' 11 " -,408 b~ = N-'B0" T~Q .... ia600 58T -' "11440 eT~ '~T~ .... '$~':"X~e ae,4 ~55 ~~ .. Q~ -' ' eel .... ~q._ 414 .. 4~4~ .~~ ..... T.~.:~-', 2~.~':: .... k,eo .... 41e~ ....... eA~o':""... ~-:.:~o~-,' ~3 ~e~'-~ .. ~,~"' .376 "-~' -N-~ -': '-479~~ ' ~2~ ,, ' .575 [ 197~ ~ '" -~70"-: '"a440 "5650-.-~gl ' ~50 ...... ....... ~ :~4 '"E4.O' ~55- L .... 1440 ..... · ~Oe0'_ a~7~, "' ~- ...... ' 'T'7 '~::s'~ ..... :39 'ga.o- ~-4 ~.[ ":iB~ ~3-- ~ ~35 ~3~. .. ~:. ... .... . ......... ' .... ' -'- . ,~ TONY KNOWLES, GOVERNOR ALAS~ OIL AND GAS CONSERVATION COMMISSION July 27, 1999 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-754.2 Scott Webb Regulatory. Coordinator Ocean Energy Resources, Inc. 1670 Broadway, Suite 2800 Denver, CO 80202-4826 Re; Pioneer Unit 1702 15DA WDW Ocean Energy Resources. Inc. Permit No: 99-64 Sur. Loc. 527'FEL, 1354'FSL. Sec. 15: T17N, R2W, SM Btmhole Loc. 527'FEL. 1354'FSL, 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 by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Your request for a variance on the surface diverter system is not approved. Please note that although this permit grants permission to drill this well, Disposal injection will not be authorized until a Pioneer Unit Disposal Injection Order is issued by the Commission. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before drilling below the surface casing shoe, must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission at 279-1433. Sincgr~5~'~ /~ / Robert N. Christ~nson, P. E. Chairman BY ORDER OF THE COMMISSION dlf/Enclosure CC; Department of Fish & Game. Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Ocean~2nergy Subject: Ocean Energy Date: Fri, 16 Jul 1999 19:32:33 EDT From: DAcke60092@aol.com To: Blair_Wondzell@admin.state.ak.us To: State of Alaska Oil & Gas Conservation Commission Mr. Blair Wondzell Ocean Energy Resources Inc. would like to request a variance on the surface diverter system. The regulations require a diverter with a size equal to hole diameter. We are drilling a 12 1/4" hole and the only diverter spool available is with a single 10" outlet. We will have a minimum of 75 ft of 10" line from the diverter. With the history of the area we feel that a 10" line is would be adequate. Respectfully, Dennis Ackerman Company Representative Drilling Supervisor Ocean Energy Resources, Inc. 1 of 1 7/16/99 3:33 PM DRILLING PROGNOSIS PIONEER UNIT "TIGHT HOLE" WELL: #1702-15DA FIELD: Pioneer Unit DIRECTIONS to LOCATION: From Anchorage, AK: SURFACE LOCATION: NE SE Section 15, T17N, R2W, Matanuska-Susitna Borough, Alaska ELEVATIONS: GL: 265' & KB: 276' 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 GENERAL 1999 PIONEER UNIT DRILLING PIONEER PROSPECT #1702-15DA Section 15, T17N-R2W Matanuska-Susitna Borough, Alaska 1.) 2.) 3.) 4.) 5.) 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 # # 1702-15DA DWI901 AFE'd Costs Dryhole Costs: Completion Costs: Total D&C Costs: $328,220. $416,553. $744,773. The #1702-15DA 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. Moming 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) 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. 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 nm a "clean" operation should be made during drilling and completion of this well. PIONEER #1702-15DA MATANUSKA-SUSITNA BOROUGH, AK DRILLING PROGRAM LOCATION: 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 (ml) No Control pH No Control PV (cp) 15 to 20 YP (lbs/100 ft2) 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#/ft J-55 STC 3,520psi/8.80 2,020psi/6.313 Tension/SF 394 Mlbs/15.63 (J) PIONEER #1702-15DA MATANUSKA-SUSITNA BOROUGH, AK SURFACE HOLE: Surface to700' (continued) SURFACE 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 gal/bbl SAPP -400 sxs "G" cmt + 2.0 % CaC12 and 1 gal/100 sx FP-6L -Displace with fresh water. Cement Properties S'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: WELLHEAD and BLO WO UT 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 #1702-15DA MATANUSKA-SUSITNA BOROUGH, AK PRODUCTIONHOLE: 700' TO 4,100' After 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. . Always wash and ream the last two (2) joints of drill pipe to bottom while tripping back to bottom 3. Always slow trip speed down to no more than 60 seconds per stand below 2500 fi 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. PRODUCTION 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 OERI 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) API Filtrate (ml) 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 30 to 35 20 to 25 13 to 24% PIONEER #1702-15DA 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/SFL-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 cm 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 gl 702-15DA GL = 265' KB = 276' 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/(276') 510'/(-234') 1,030'/(-754') 1,300'/(-1,024') 1,765'/(-1,489') 2,250'/(-1,974') 3,175'/(-2,899') 3,420'/(-3,144') 3,600'/(-3,324') 4,100'/(-3,824') 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. PROD 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 #1702-15DA MATANUSKA-SUSITNA BOROUGH, AK PROD UCTION HOLE: 700' TO 4,100' (Continued) PRODUCTION 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 4hfs WOC after 1 st stage before pumping 2nd 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 of 4hrs 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 (#/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. Wellheath Land casing in full tension & set slips. ND BOPE & Make cut on 7" casing. Nipple up tubing head. PIONEER #1702-15DA 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 4,100' 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 = $3,569.83 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 #1702-15DA 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 #1702-15DA 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: 0- 0- O- 10 BLOWOUT ~"_ ,'E~". ,NTER SYSTEM Pioneer Unit Ocean Energy, Inc. Fill Line Flow Line Diverter Rating: 3,000 psi Active 5,000 psi Static Choke Manifold Assembly for 3M WP System To Pit and/or Mud/Gas Separator Adjustible Choke I Annular I I R-Pipe Rams I I R-Blind Rams I I !Spool! I KillLinesI 3000 PSI WP Choke Line Blowout Preveter Stack Outlet Choke Line Bleed Line to Pit To Pit Adjustible Choke Ocean Energy Resources, Inc. Alaska Coal Bed Methane Drilling Program Pioneer Unit 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 2~ ATTACHMENT #1 Ocean Energy Resources, lnc requests a waiver to not utilize a dlverter during drilling of the 12-1/4" Surface Hole duc to no shallow gas down to 700' below surface. Ocean Bnergy Resources, Inc will perform an 11,5 ppg FIT by drilling 10 feet below thc 9-5/8" Surface Casing Shoe, then pumping to an equivalent mud weight test to 11.5 ppg at the surface casing shoe, Oil & Gas Cons. Anchorage NE 1/4 SE 1/4 SECTION 15 T17N, R2W, S.M., AK Proposed Surface Facilities GL : 265' P~ONEER ~ 5DA GRID N: 2762483.047~ GRID E: 569295.57.9.~ LATITUDE: 61'33'37.043111 LONGITUDE: 149'36'09.349'~J ASP ZONE 4 NAD27 South Line Section 15 SCALE 1"= 200' 1) Basis of Horizontal Coordinates State of Alaska DOT&PF Georeferencing Project OPS Control Stations BigL & G40. Pad-- _-Nell 527' Access Rood monument 1554' Found survey monument OCEAN ENERGY, INC. PIONEER UNIT II4702-15DA SURFACE LOCATION 527' FEL and 1354' FSL o SECTION 15, T17N, R2W, S.M., AK MATANUSKA-SUSITNA BOROUGH Prepared For: Ocean Energy Inc. 1670 Broadway Suite 2800 Denver, CO 80202 Surveyed by:, 993060 Job No: ..... McLANE CONSULTING GROUP Engineers, Surveyors ond Plonners P.O. Box 468 Soldotno, AK 99669 99-20 June 19, 1999 Field Book No. Dote: OG:~{,.~qPM OCF'eN~, ENERGY {. P.1/E1 FAX COVER SHEET Ocean Ener~ Resources, Inc. 1670 Broadwm.,- S~ti~e 2;800 Denver, Colorado ,?0202-.<,:~£6 Telephone: (303) DENVER Of'FlEE NORTH AMERIC4 - ONSHORE OERI Fcax ~ f303) 30~%,75/0 OERI Operation ~ Fc[x ~ 4303) 308-,7697 co~,y.. ........ fi,,,,.,.O,,,¢.,,.C ,./C.. ~ ,v~m&~: ( ..... ,,q, ,,,O? .......... ) ,,276 - 7 ~/~. , ......... .................... ............................................................................................................................................. ~,,,, ~,~,~,. .................... ~,.! .............. (Includes cover ~l~eri .....t- .... _~ '":t ..................... ......... "'"'"": ............. '" ......... P~"x ........................................ '~'" ..... " ................. ~'~'" ..... ,......~. ........... ~... ..... ,...,..~.~..., ........ .~ ........ ,.,....,.,..,,.....~0,.~ ................. ~.,, ......... , ........................ ~ ............. ...... ~.~ J ........... ~....~..~:,...~ ........... t.u.c..~ .... ,~ ......... ~,.~ .... ~:o.,,.~..~,. ~.....~:.~...,..,.~4 ...,..~ .... ~.~...~ ........... ~.~..m.~,.~ .............. ,..~ ......... ,..:V.& ........ '~~k ............ y.,...~..~ ................................ ............................................................................................. , ,,..,',,, ,' ,' .............................................. ~'. .................................. l "" ' ' ........................................ ' ...... ................................................................................................................................................. 7_~.:~..~...l.v.. ~ ................................................ .... ,'. , '..,',, ',. '.':",' .'. ".' :', ....... :, , ,. . .. ........ ,.'.. ,',,',",",'..,' " ', " . . ' . ', '"' "," If you do not receive all ~h~ fax,d p~es as indmatea adore or iz you ge~ mi, mx m ~ r. P follow~n$ telephone number (30~) ~084500. 06: 2'qPM OCEI2N ENERGY P.2/21 July 7, 1999 Alaska Oil and Oas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: Drilling and Recompletion Plans Pioneer Unit . Matanuska-Susitna Borough, AK Dear Mr. Blair Wondzell: Thank you for your assistance on completing the AOGCC APD requiremems for the upcoming Pioneer Unit project. Ocean Energy Resources, Inc plans to start work on the Pioneer Unit'pmject with spud of the first well tentatively planned for the week of July 19, 1999. Attached are, copies of the drilling prognosis for the three planned new wells (two producers and one water disposal). All of the wells will be drilled with a closed loop mud system, which will eliminate the need for drilling pits. An agreement has been finalized with Mat-Su Borough for disposal of dc~vatered solids from the drilling fluid in their Central Landfill after pre-disposal testing has determined that thc solid~ are free of hazardous contaminates.. Remaining liquids from the drilling fluid will be disposed by injection into the proposed water disposal well, #1702-15AD, which is the first well planned for drilling in the project. No drilling fluids will be disposed by means of annular injection during drilling of any of the wells planned for 1999. Detailed completion procedures will be submitted to AOGCC after analysis of openhole logs from each of the wells. Also attached to this letter is a copy of the Lone Star Steel Company casing performance properties as you requested. We will contact Lone Star Steel Company tomorrow to have two copies of their catalog mailed to your attention. Chuck Wilson, Rob Downey and I w/Il be in Anchorage, AK from July 13~' to July 16~ to finalize plans for this project. During our visit next week, we would like opportunity to introduce ourselves at your convenience. Please call either myself at (303) 308 - 8867, Rob Downey (303) 308 - 8822 or Chuck Wilson at (303) 308 - 8864 with any questions concerning our plans. Sincerely, Douglas L. Walton Rocky Mountain Area Production Manager O.~n 8nlttl]¥ RO~OII~, Ind. Amw, o [t~.fl~ 1670 Broadway, Suite 2800 Denver, Colorado 80102 (30.3) 308-8500 Fax: (3(33) 308-8510 Initial Pioneer Unit Drilling PrograTq:~,,,~ Ocean (E"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_christenson~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 OCEAN ENERGY RESOI,[ ~.S, INC. 410-17th Street, Suite 1400 Denver, Colorado 80202 (303) 573-5100 PAY THE SUM OF One hundred and 00/100 Dollars TO THE ORDER OF NationsBank, ~ A'~anta, Dekalb County, 6..,,orgia 64-1278/811 No. 05130137108 DATE JUN 18,1999 AMOUNT *****$100.00 VOID AFTER 90 DAYS ALASKA OIL & GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, AK 99501 OCEAN ENERGY RESOURCES, INC.410-17th Street Suite 1400 * Denver, Colorado 80202 * (303) 573-5100 · ' ' ; '., ,'. '.:, .,.; .:..i..... .... · . .': · · : ,' , .,; . ..' : .':' '. : 'i: . '. · :'":." 061499B 06/14/99 342683 APD FOR PIONEER 100.00 100.00 UNIT # 1702-15DA, ALASKA I WELL PERMIT CHECKLIST FIELD & POOL ADMINIS¥~,ATION ENGINEERING DATE 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from ddlling 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 ........... COMPANY~C~',~x.,) ~Je. WELL NAME/~'O'Z.-/.gD.4 c,,,a~o PROGRAM: exp dev redrll serv ,_~_ wellbore seg ann. disposal para req GEOLOGY 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. Ifa re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to P__~7OO 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 ................. 30. Permit can be issued w/o hydrogen sulfide measures ..... GEOL AREA ~_,,--~ UNIT# ON/OFF SHORE N N N N N N (~N ~)N (~)N (~N ANNULAR DISPOSAL APPR DATE 31. Data presented on potential overpressure zones ....... Y~" ' 32. Seismic analysis of shallow gas zones ............. 33. Seabed condition survey (if off-shore) ............. / 34. Contact name/phone for weekly progress reports [exploratory oj~¥] Y N 35. With proper cementing records, t~.bis~plan (A) will contain waste in a~saitable receiv~ipg zone; ....... Y N (B) will not contam~at~ freshwater; gr~dause drilling wa~e... Y N to surface/ ~/' ~ (C) will n~Af~pair mechan~egrity of the_~v~sed for disposal; Y N (D) will [~ot damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOL~);~,~ ENGINEERING: UlC/Anj3~lar COMMISSION: co ~o ~,/~.~[~ Comments/Instructions: Z -I 131 Z c:\msoffice\wordian\diana\checklist
