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Home My WebLink About199-065GE{7lOCiC MATERIALS CENTER NEWiNUENTORY ~^`r_it~~_, %~~~ r .._. .. jaa~-o~~) pMC lOCA71 ON WELL NAME WELL NO API SE7 NUMBER OPERATOR? TYPE METNOp TOP BOTTOM BO% COMMENTS tj _.__ .`E,a. :_G L; 1. ,'irr ry1 '~, ~o~. )i ~ry r5~X2~^ ~ _..._..«. ~.~ ........ ._. ~ ._ ol,.b ~ ~~~ ._.._._. I ,. ~~ l ; ~. ...... ' ~~. Page DO~FhT~p f3i I^RVL Lft'trf{ L~vhE fit{~~Ct~~ e e MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 'V '/Iei{ P. I. Supervisor ~er¡ ') I ¡ Uý> DATE: May 8'F ;)-ODC? FROM: John Spaulding, Petroleum Inspector SUBJECT: ...olu5' Location Clearances \f!{. q Pioneer Unit Pioneer Natural Res. The following wells in the Pioneer Unit were inspected for location clearances: Bering 03 PTO: 202-177 Baranoff 04 pro: 202-178 Cook 01 PTO: 202180 Lowell 02 pro: 202-179 ~02-14CC PTD: 199-065 1702-150A WOW PTO 199-064 1702-1500 PTO: 199-066 Cornhusker 04 pro: 202-181 RL Smith 03 pro: 202-182 OL Smith 01 PTO: 202-184 Stromberg 02 PTO: 202-183 BL T 01 PTO: 199-068 . 4>< )\ ~h"~ r,;f ' ~\I't'... 1¡., ~~,:.., ..;.. t-;.~ All locations were found to be in excellent shape, well graded with some small amounts of debris. I requested that the debris be cleaned up and Joe Polya Pioneer Nat. Resources rep. agreed. He will inform as to when the final cleanup has been made so that I may make one last pass over the locations. SUMMARY; I found all locations in very good condition with small amounts of tidying up to be done. Attachments: photos on CO NON-CONFIDENTIAL Well location Vine Road in off Water Wen _ STATE OF ALASKA . ALAS~L AND GAS CONSERVATION COMMIS N RECEIVEr) WELL COMPLETION OR RECOMPLETION REPORT A6ID '- "L' 1a. Well Status: OilU GasU' Plugged L.:J /Abandoned L.:J Suspended U WAGU 1 b. 'lin!1 ila~; 20AAC 25.105 20AAC 25.110 DeveloP~~ ~ Gas C~I~~El GINJD WINJD WDSPL 0 ". . £ U "'1 No. of Completions Other Service 0 ~ Aim' ic Test 2. Operator Name: 5. Date Comp., Susp., or 12. Permit to Drill Number: Pioneer Natural Resources Alaska, Inc. Aband.: Aug 19,2005 1~/ 3. Address: 6. Date Spudded: 13. API Number: 700 G Street, Suite 600 Anchorage, AK 99501 August 28, 1999 50-009-20016-00 ~ 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 820' FSL, 500' FWL, Sec 14, T17N, R2W, SM November 12,1999 1702-14CC ~ Top of Productive Horizon: 8. KB Elevation (ft): 15. Field/Pool(s): 749' FSL, 704' FWL, Sec 14, T17N, R2W, SM 281 Total Depth: 9. Plug Back Depth(MD+ TVD): Pioneer Unit 517' FSL, 1142' FWL, Sec 14, T17N, R2W, SM Surface 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 570397 y- 2762023 (NAD 27) Zone- 4 4050 MD ADL 374117 TPI: x- 570601 y- 2761954 Zone- 4 11. Depth Where SSSV Set: 17. Land Use Permit: Total Depth: x- 571041 y- 2761724 Zone- 4 NA NA 18. Directional Survey: Yes L.:J No U 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 K-55 Surface 677 Surface 677 12.25 400 sx class G None 7 23 CF-50 Surface 4034 Surface 3934 apprx 8.75 856 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 ."..~,.,-,,,,,,-~<.- 3.5 2561 2671 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 2680-3284 28 bbl Type I cement sqz below packer / "ANNP" (1 l' 2005 st"" ',i=') t,j ~ 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: I Gas-Oil Ratio: Test Period .... Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity - API (corr): Press. 24-Hour Rate ~ 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None nR\G\NÞ\L ~ ~¡:3i)r).5. ".., to, [~~(O~- Form 10-407 Revised 12/2003 CONTINUED ON REVERSE n G~ ~ \O¿; \',o \ ,0\ ~ NAME GEOLOGIC MARKERS MD 29. ORMATION TESTS 28. TVD Include and briefly sum e test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". None 30. List of Attachments: Final Well Schematic, Operations Summary 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Printed Name: Joe Polva Signature: Title: Sr. Staff Drilling Engineer - Phone: 907-343-2111 Date: INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for / njection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 e e Pioneer Natural Resources Alaska, Inc. Pioneer Unit 1702-14CC Plug and Abandonment Operations Summary August 11, 2005 Check well for pressure, water to surface in tubing and annulus, 680 psi on tubing. Test casing/tubing annulus to 1500 psi, test good. Batch mix and pump 28 bbl15 ppg Type I cement down tubing and squeeze perforations below packer. Injection pressure 1500 psi initially dropping to 1100 psi during pump job, 2.5 to 3 bpm. Drop foam wiper ball and displaced cement with 23 bbl water. Displacement pressure 1900 psi at 2.5 bpm. Shut in well at 600 psi. SDFN. August 12, 2005 Pressure test squeeze job to 1100 psi for 15 minutes, test good. RD triplex pumps and move to 1702-15DA- WDW. Waiting on Pollard Wireline for tubing punch. August 13, 2005 Waiting on Pollard Wireline for tubing punch. August 14, 2005 Wait on Pollard Wireline for tubing punch. Rig up Pollard, RIH with tubing punch, could not get below 2468 feet. Punch tubing from 2464 to 2468 feet. POOH and RD Pollard. RU cementing lines on tubing and pump 10 bbl water to ensure circulation. Batch 90 bbl15 ppg Type I cement and pump same down tubing taking returns out annulus. Clean up equipment, SDFN. August 15,2005 Cut off well to 5 feet below ground level. Perform minor top job on 3-1/2 x 7 inch and 7 x 9-5/8 inch annuli to achieve cement to surface. August 18, 2005 Chuck Sheve ofthe 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. - 1 - e Pioneer Natural Resources Alaska, Inc. 1702-14CC Plug and Abandonment Photos Photo 1: Rigging down injection lines and rigging up cementing equipment. -2- Photo 2: Excavating around well prior to cut off of well 1702-14CC. - 3 - Photo 3: 1702-14CC well cut off and cement to surface. Photo 4: 1702-14CC with marker plate installed. -4- Pioneer Unit 1702-14CC Final Well Schematic Well 1702·14CC API 50-009-20016-00 Qtr/Qtr Sec 14 Pioneer Natural Resources Alaska, Inc. Twp 17N Rng 2w r T Size Depth County Matanuska,Susltna State Alaska 677 Field Pioneer Unit Country USA 7 23 ppf ~ 3-1/2 I 9.3 OD Des N/A N/A 3834 4 N/A N/A 3 3748 6 4 3718 6 N/A 5 3582 8 N/A Derf 5 spf HCS 6 :520 ~ H N/A Alpha Set 7" CIBP 7 N/A 8 N/A N/A 3202-3268 perf 4 spf ~ 3184 10 NI N/A 2862 44 NI N/A 11 2680 54 NI ËR 7.67 6. 1 2072 2.3 4 15 surface ell cuttoff 16 2468 4 3-1/2 inch t - ~ =J t = =î ~ I 15 Modified by JRM 14-sep-C ) ) tqq ~ oCø c:; Pioneer Natural Resources Alaska, Inc. Plug and Abandon Procedure Pioneer Unit 1702-14CC Well Revision 1, August 5, 2005 The Pioneer Unit 1702-14CC well was drilled in 1999 by Ocean Energy for coal bed methane evaluation and was later converted by Evergreen to a water disposal well. The well has 9-5/8 inch surface casing set at 677 feet and 7 inch production casing set at 4212 feet. Both the 9-5/8 and 7 inch casing strings have been cemented to surface. The completion for the well is 2-7/8 inch tubing with a packer set at 2671 feet. The well is also perforated at various intervals from 2680 to 3883 feet. Attachment 1 shows the current 1702-14CC well diagram. Pioneer Natural Resources Alaska, Inc. (Pioneer) proposes the following P&A procedure to plug the well in accordance with AOGCC regulations. Pioneer is requesting a variance from the Well Plugging Requirements, 20 AAC 25.112, to leave the lower set of perforations unsqueezed in the wellbore. We believe that adequate protection to fresh water sources will be provided by the P&A program described below. The proposed final 1702-14CC well diagram is presented in Attachment 2. 1. Verify all permit paperwork is in place and give AOGCC 24-hour notice of intent to begin well work operations and intent to cement well and give AOGCC representative chance to witness same. Verify that a variance from the AOGCC has been obtained for leaving the lower perforations in the well unsqueezed before starting work. 2. Mobilize necessary equipment and personnel to location. 3. Check for pressure on casing and tubing. Expect to see 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 1500 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 (expect no pressure on annulus due to reported surface cement job on 7 inch casing). 4. Mix and pump 28 bbl, 15 ppg, Type I cement down tubing and squeeze perforations below packer. Insert foam wiper ball in tubing and displace cement in tubing with 23 bbl water. Clean up equipment, WOC 12 hours. 5. Test plug below packer to 1100 psi. 6. Rig up slickline unit for tubing punch. RIH and punch tubing with minimum 4 holes at 2660 feet MD. 7. Mix and pump 96 bbl down tubing and up annulus to fill well with cement. WOC. 1702-14CC P&A procedure rev 1.doc - 1 - SCi\NNEC' AUG ¡) 9 2005 ') ) 8. 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 cutoffwell. 9. Weld on well ID marker plate (1/4" x 24" x 24") with the following information bead welded on plate: Pioneer NRA APD: 199-065 Pioneer Unit 1702-14CC API: 50-009-20016-00 Backfill well excavation and grade for positive drainage. Perform complete site inspection immediately after P&A operations if AOGCC inspector is available. 1702-14CC P&A procedure rev 1.doc - 2 - e MEMORANDUM TO: .r~, ¡ / f:' /) ..-" '\<:;1'1 { f Jim Regg, P. I. Supervisor FROM: Chuck Scheve, Petroleum Inspector e State of Alaska Alaska Oil and Gas Conservation Commission OJ ,..)--'" I L?¡U) DATE: August 18, 2005 SUBJECT: Surface Abandonment Pioneer Unit Willow Fishhook #1 PTO# 203-207 1702 14CC PTQ# '99-065 1702 150A-WO PTO# 199-064 1702 1500 PTO# 199-066 BL T-01 PTO# 199-068 Thursdav. 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 15 DO .JPG BL T-01. JPG ~C'\\N.NEU C ?, 1 2.GÜ5 "..:>/ .... t-" ., .~. Pioneer I 702 ¡ 4CC to Surface 2 Plate (.-' '1~1 ~~./ß';\ ?Œ ", l' Ii '¡ ¡ ¡ i ~ 'I f ;; ~ \ I I I' f' I-!,:' ¡ 1 ~ Il II' /1 i.\ lJ' il /) !.- I' I, ) I In '\ r-C' i '. \\ 'll œ:/..., l'ñ) :1'"1/7' ! ¡ ¡ i.' Ii I ~ ii/!' \ ! i ./)\ I"~ \~,,:<~ ! !Yi; / A \ '\! I'. . J !Jlj!!Ji ~ :1 dj\, '\\1" ~ LRiJ, ! I ,,'I I 1,_ I' ; ,\ 11 I I, \~ ¡, \ lJ:¿) U 'i \ \ i~ U U (~j .l! Ü: i \ ~ ') AItA~1iA OIL AND GAS CONSERVATION COMMISSION / / I / 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 flIb' ",., r:::'", "'.":- ".'" "" fl,·\,,: '.', "' ~,.., ,.ß\:;'Y'~~": ',' \~. ,(, ." \ ., Re: Pioneer Unit 1702-14CC Sundry Number: 305-197 SC.ANNED JUt 2 S 2005 Dear Mr. Polya: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely: GO Daniel T. Seamount, Jr. Commissioner ~J, DATED this2"Z... day of July, 2005 Enc!. ) July 19, 2005 Mr. Winton Aubert Alaska Oil and Gas Conservation Commission 333 W. 7th Ave #100 Anchorage, Alaska, 99501-3539 RE: Sundry Approval (Form 10-403) Pioneer Unit -1702-14CC Well Plug and Abandon RECEIVED JUL 2 0 2005 Alaska Oil & Gas Cons. Commission Anchorage Dear Mr. Aubert: Attached is the 10-403 form requesting approval to Plug and Abandon the 1702- 14CC 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 requests a variance from the AOGCC plug and abandonment requirements in the attached P&A proposal. Pioneer's plan calls for squeezing / the upper set of open perforations in the well while the lower set that is below a CIBP is planned to be left as is. Pioneer believes that the attached P&A program provides adequate protection of fresh water resources. If you have any questions, please feel free to contact me at 907-343-2111 or polyaj@pioneernrc.com. Sincerely, ~~~. Joe Polya Sr. Staff Drilling Engineer Pioneer Natural Resources Company 700 G Street, Suite 600 Anchorage, AK ()'Jt,J;~t "'f)~ \l.JGI~ T/l·¡I"LðO,>· STATE OF ALASKA' t( . ALAS. )OIL AND GAS CONSERVATION COMMI~h...bN CEIVED APPLICATION FOR SUNDRY APPROVAL JUL! 6 2005 20 MC 25.280 Operational shutdown U Plug Perforations D Perforate New Pool D 4. Current Well Class: Abandon l:J Alter casing D Change approved program D 2. Operator Name: Pioneer Natural Resources Alaska, Inc. 1. Type of Request: 3. Address: 700 G Street Suite 600 Anchorage, AK 99501 7. KB Elevation (ft): 281 ft KB (ii' AGL) 8. Property Designation: Private 11. Total Depth MD (ft): 4050' M D Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): 2680 - 3284 Total Depth TVD (ft): 4050' TVD Length n/a 35 feet 666 feet n/a 4024 feet n/a Suspend U Repair well D Pull Tubing D Perforate Alaska Uil & 'fJs'EGImI. ComrflÎ$SßWer U Stimulate D Time Ex~m:f¥ò'¡; e Re-enter Suspended Well' L 5. Permit to Drill Number: Exploratory ~ 199-065 / Service ~ 6. API Number: / 50-009-20016-00-00 Development Stratig raphic D D 9. Well Name and Number: <,,/ 1702-14CC 10. Field/Pools(s): Pioneer Unit (610500) PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth ND (ft): 3945' MD 3945' TVD Size n/a 13.375 inches 9.625 inches n/a 7.000 inches n/a Perforation Depth TVD (ft): 2664 - 3232 Packers and SSSV Type: Arrow Set AS1-X Plastic Coated Packer 12. Attachments: Description Summary of Proposal U Detailed Operations Program 0 BOP Sketch D 14. Estimated Date for Commencing Operations: 16. Verbal Approval: ...",_.~-' 7/3.tf2Ô05 ,/ Date: Plugs (measured): PBTD 3562' MD Burst n/a nla 3520 psi n/a 4000 psi n/a MD TVD n/a n/a 46 feet 46 feet 677 feet 677 feet n/a n/a 4034 feet 4034 feet n/a n/a Tubing Size: Tubing Grade: Junk (measured): NONE Collapse n/a n/a 2020 psi n/a 3110 psi n/a Tubing MD (ft): 3-1/2" 9.3 ppf J55 2651 Packers and SSSV MD (ft): Packer set @ 2671 ft. md. 13. Well Class after proposed work: \dGk' Exploratory ~ Development D Service [![ 15. Well Status after proposed work: Oil D Gas D Plugged 0 Abandoned 0 WAG D GINJ D WINJ D WDSPL D Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Joe Polya Printed Name Joe Polya Title Sr. Staff Drilling Engineer Signature >- ~\ ,;1)... a..-- Phone 907-343-2111 Date \. - r COMMISSION USE ONLY 7J1 HOOO&~ Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 7/ZØ/ZOoC 3pS--197 Plug Integrity D BOP Test D Mechanical Integrity Test D Location Clearance œ( Other: ¡)N 'W A-A c..l. S · II ¿ (I) , .....1 hf/'l,.<.- f<- Lv.ÆÎ I ¡'J kr '1 ¡""'I f W Cf h Me I S ",_p pW I/€ J . RBDMS 8Ft JUL ?.5 2005 Subsequent Form Required: (0 - A. 0 7 . Original Signed By DAN SEAMOUNT Approved by: Form 10-403 Revised 11/2004 COMMISSIONER APPROVED BY THE COMMISSION Date: \ f-" ì :':'\\ f\ L ' f \" '/ OR'0\,\\\Ø-\ Submit in Duplicate ') ) Pioneer Natural Resources Alaska, Inc. Plug and Abandon Procedure Pioneer Unit 1702-14CC Well The Pioneer Unit 1702-14CC well was drilled in 1999 by Ocean Energy for coal bed methane evaluation and was later converted by Evergreen to a water disposal well. The well has 9-5/8 inch surface casing set at 677 feet and 7 inch production casing set at 4212 ¡",,/ feet. Both the 9-5/8 and 7 inch casing strings have been cemented to surface. The completion for the well is 2-7/8 inch tubing with a packer set at 2671 feet. The well is also perforated at various intervals from 2680 to 3883 feet. Attachment 1 shows the current 1702-14CC well diagram. Pioneer Natural Resources Alaska, Inc. (Pioneer) proposes the following P&A procedure to plug the well in accordance with AOGCC regulations. Pioneer is requesting a variance from the Well Plugging Requirements, 20 AAC 25.112, to leave the lower set of perforations unsqueezed in the wellbore. We believe that adequate protection to fresh water sources will be provided by the P&A program described below. The proposed // final 1702-14CC well diagram is presented in Attachment 2. 1. Verify all permit paperwork is in place and give AOGCC 24-hour notice of intent to begin well work operations and intent to cement well and give AOGCC representative chance to witness same. Verify that a variance from the AOGCC has been obtained for leaving the lower perforations in the well unsqueezed before starting work. 2. Mobilize necessary equipment and personnel to location. 3. Check for pressure on casing and tubing. Expect to see 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 1500 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 (expect no pressure on annulus due to reported surface cement job on 7 inch casing). Rig down pressure test lines. 4. Rig up slickline unit for tubing punch. RIH and punch tubing with minimum 4 holes at 2660 feet MD. 6. 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 (i.e. tubing and annulus :~:s::s ;:l~::l~ ::m:p:~:y::i;::::~:own annulus with tubing shut in and simultane~:Jy inject annular fluids into perforations below packer. Shut in annulus when 73 bbl pumped. Quickly swap pump line over to tubing and inject 5. 1702-14CC PA procedure. doc - 1 - 7/19/2005 12:49 PM ) ) ,// an ~dditiona)15~/,lj~1 of ~ement down tubin~ to s~ueeze perforations below the tubIng and fill: 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. 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: 199-065 Pioneer Unit 1702-14CC API: 50-009-20016-00 Backfill well excavation and grade for positive drainage. Perform complete site inspection immediately after P&A operations if AOGCC inspector is available. 1702-14CC PA procedure. doc - 2 - 7/19/2005 12:49 PM ) ) Attachment 1: Pioneer Unit 1702-14CC Current Well Schematic 1~ Well 1702·14CC API 50-009-20016-00 !,~¡. ~j ~,f ¡ ~~"\ ~"" Qtr/Qtr See 14 Pioneer Natural Resources Alaska, Inc. ';:' ...';', ~~"JII' ~...:~ ,(",'iI'i Twp 17N Rng 2w r~ : I ,~;. "I\'!~ Size Weight Grade Thread Depth :~ I} I~~~ County Matanuska,Susitna State Alaska Casing 9·5/8 36 ppf J·55 ST&C 677 ~~ ~~~ ~'~ ~~:~ ~ Field Pioneer Unit Country USA Casing 7 23 ppf CF·50 LT&C 4034 -¡ GUKB 269/281 Tubing 3·1/2 9.3 J·55 8rd 2651 " :1 I !Ï No. I Depth I Length I 00 10 Description k'«lr::,: 1 3878 5 N/A N/A 3878-3883 perf 5 spf HCS Ii'~' il'l, ,ill ~r'¡ 2 3834 4 N/A N/A 3834-3838 perf 5 spf HCS I,,~ 3 3748 6 N/A N/A 3748-3754 perf 5 spf HCS ../ ~iiÎ 4 3718 6 N/A N/A 3718-3724 perf 5 spf HCS C 5 3582 8 N/A N/A 3582-3590 perf 5 spf HCS 14 6 3520 2 N/A N/A Alpha Set 7" CIBP ".- 7 3275 9 N/A N/A 3275-3284 perf 5 spf HCS 8 3202 66 N/A N/A 3202-3268 perf 4 spf 23 gram 0.45" premium 13 9 3184 10 N/A N/A 3184-3194 perf 5 spf HCS 10 2862 44 N/A N/A 2862-2906 perf 4 spf 23 gram 0.45" premium 12 11 2680 54 N/A N/A 2680-2734 perf 4 spf 23 gram 0.45" premium 12 2671 7.67 6.125 3 Arrowset AS 1-X Plastic Coated Packer 13 2662 1.1 2-875 2.25 Standard seat nipple 14 2072 2.3 4.5 8.188 Gemco Md 715E stage collar (drilled out) 11 10 9 8 7 6 4 3 2 PSTD 3945 Modified by JRM 9-JUL-05 ) ) Attachment 2: Pioneer Unit 1702·14CC Proposed Final Well Schematic 5 Well 1702·14CC Qtr/Qtr Sec Twp 17N Rng API 14 50-009-20016-00 Pioneer Natural Resources Alaska, Inc. 2w Size Weight Grade Thread Depth County Matanuska,Susitna State Alaska Casing 9-5/S 36 ppf J-55 ST&C 677 Field Pioneer Unit Country USA Casing 7 23 ppf CF-50 LT&C 4034 GUKB 269/281 Tubing 3-1/2 9.3 J-55 Srd 2651 No. I Depth I Length I OD ID Description 1 3878 5 N/A N/A 3878-3883 perf 5 spf HCS 2 3834 4 N/A N/A 3834-3838 perf 5 spf HCS 3 3748 6 N/A N/A 3748-3754 perf 5 spf HCS 4 3718 6 N/A N/A 3718-3724 perf 5 spf HCS 5 3582 8 N/A N/A 3582-3590 perf 5 spf H,ÇS 14 6 3520 2 N/A N/A Alpha Set 7" CIBP .,/ 7 3275 9 N/A N/A 3275-3284 perf 5 spf HCS, SQUEEZED 8 3202 66 N/A N/A 3202-3268 perf 4 spf 23 gram 0.45", SQUEEZED 13 9 3184 10 N/A N/A 3184-3194 perf 5 spf HCS, SQUEEZED 10 2862 44 N/A N/A 2862-2906 perf 4 spf 23 gram 0.45", SQUEEZED 12 11 2680 54 N/A N/A 2680-2734 perf 4 spf 23 gram 0.45", SQUEI;ZED 12 2671 7.67 6.125 3 Arrowset AS1-X Plastic Coated Packer r 13 2662 1.1 2-875 2.25 Standard seat nipple 14 2072 2.3 4.5 8.188 Gemco Md 715E stage collar (drilled out) 15 surface Well cuttoff 5 feet below original ground level 11 10 9 8 7 4 3 2 11 ~ ~~" PBTD 3945 Modified by JRM 9-JUL-m STATE OF ALASKA (' ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: OilF3 Gas[-I Plugged[-'~ Abandoned[] Suspendedl--] WAG[-] lb. Well class: - 20AAC 25.105 20AAC 25.110 Development [] Exploratory [] GINJI--] WINJI--] WDSPL[] No. of completions~ Other REVISED Service [] Straticjraphic Test [] 2. Operator 5. Date Comp., Susp., 12. Permit to Drilt Number: Name: Evergreen Resources Alaska Corp. or Aband.: 5131103 199-0650 , , 3. Address: 6. Date Spudded: 13. APl Number: P.O. Box 871845 8/28/99 50-009-20016-00 Wasilla, AK 99687 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: SW/SW Sec 14 Twn 17N Rng 2W, Seward Meridian 11/12/99 1702-14C0 Surface: 820' FSL 500' FWL 8. KB Elevation (ft): 15. Field/Pool(s): Top of Productive 281 ft KB Pioneer Unit (610500) Horizon: 749' FSL 704' FWL 9. Plug Back Depth (MD + Total Depth: 517' FSL 1142 FWL TVD): 3562' KB MD 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD + TVD): 16. Property Designation: Sec 14 Twn 17N Rng 2w 4050' KB MD Private Surface: x- 570396.8196 y- 2762023.2995 Zone-4 11. Depth where SSSV Set: 17. Land Use Permit: TPh x- 570601.3183 y- 2761953.5995 Zone-4 N/A feet MD NIA TotalDepth: x- 571040.9523 y- 2761724.4013 Zone-4 19. Water Depth, if Offshore: 20. Thickness of Permafrost: N/A 18. Directional Survey: Yes[] No[] N/A feet MSL 21. Logs Run: Cmt Bond Log 22. CASING, LINER AND CEMENTING RECORD CASING WT. SETTING DEPTH MD SETTING DEPTH TVD AMOUNT SIZE PER GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED FT. 13-3/4 36 N/A 0 35 0 35 16 30 sx Concrete 9-5/8 36 J-55 0 677 0 677 12.25 84 bbls Class A 7 23 CF-50 0 4034 0 4034 8.75 142 bbls Class G , ,, 23. Perforations Open to Production (MD + 'I'VD of Top and Bottom 24. TUBING RECORD Interval, Size, and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) 3275-3284, 0.45" 23 gram, 45 holes ~ 5 spf 3202-3268, 0.45" 23 gram, 264 holes ~ 4 spf 3-1/2 2652 2661 3184-3194, 0.45" 23 gram, 50 holes (~ 5 spf , 2862-2906, 0.45" 23 gram, 176 holes @ 4 spf 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 2680-2734, 0.45" 23 gram, 216 holes @ 4 spf DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 3184-3284 .. . Borate x-link gel frac w/110,000 20140 2862-2906 Borate x-link gel frac wi 119,050 20/40 2680-2734 Borate x-link gel frac w/102,300 20140 26. PRODUCTION TEST Date of First Production: N/A Method of Operation (Flowing, Gas Lift, etc.): Water Injection ..... Date of Test: Hours Tested: Production Test OiI-Bbl: Gas-MCF: Water-Bbh Choke Size: Gas-Oil Ratio: None None for Period N/A NIA N/A N/A N/A .... Flow. Tubing Casing Pressure: Calculated OiI-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-APl (corr): Press: None 24-Hour Rate N/A N/A N/A N/A 27. . . CORE DATA . Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas, or water (attach separate sheet, Submit core chips; if none, state "none". None S,EP' 1 Form 10-407 Revised 4/2003 CONTINUED ON REVERSE SIDE Anchorage None 29. {[ ORMATION TESTS Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". None SEP $ 280 0il & Gas Cons. ~&nch0rage 30. List of Attachments: Daily Completion Reports; Treatment Reports; all above listed logs 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Shane Gagliardi Printed Name. Shan_e. Ga~liardi Title Petroleum Enqineer Signature .....-,,?AO/-~. ,,, . Phone 907-355-8569 Date 9/15/03 General: Item Item 4b: Item 8: Item 13: Item 20: Item 22: Item 23: Item 26: Item 27: Item 29: INSTRUCTIONS 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. 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. TPI (Top of Producing Interval). The Kelly Bushing elevation in feet above mean iow Iow water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The APl number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). True vertical thickness. Attached supplemental records for this well should Show the details of any multiple stage cementing and the location of the cementing tool. 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). Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). If no cores taken, indicate "none". List all test information. If none, state "None". Form 10-407 Revised 4/2003 RESOURCES (ALASKA) CORP. A Subsidiary of Evergreen Resources, Inc. September 4, 2003 Mr. Bob Crandall Senior Geologist Alaska Oil and Gas Conservation Commission 333 W. 7th Ave #100 Anchorage, Alaska, 99501-3539 RE: Completion Report (Form 10-407) Pioneer Unit - 1702-14CC Dear Mr. Crandall: Attached is the 10-407 form for the Pioneer Unit 1702-14CC. This well is used in conjunction with the 1702-15DA for brine water disposal under injection order 20. If you have any questions, please feel free to contact me at 907-355-8569 or sh.aneg~)~evergreengas.co.n~. Sincerely, Shane ~a~ Petroleum .Engineer ORIGINAL 1075 Check Street, Suite 202 o Wasilla AK 99654 P.O. Box871845 · Wasilla, AK99687 o TEL907.357.8130 · FAX907.357.8340 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: Oil[-] Gasl'-I Pluggedl-'l Abandonedl-'l Suspendedl--I WAGD lb. Well Class: 20AAC 25.105 20AAC 25.110 Development [] Exploratory [] GIN J[-'] WlNJD WDSPLI~ No. of completions__ Other Service [] Stratigraphic Test [] 2. Operator 5. Date Comp., Susp., 12. Permit to Drill Number: Name: Evergreen Resources Alaska Corp. or Aband.: 5131103 3. Address: 6. Date Spudded: 13. APl Number: P.O. Box 871845 8128199 50-009-20016-00 Wasilla, AK 99687 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: 11/12/99 1702-14CC Surface: SW/SW Sec 14 Twn 17N Rng 2W, Seward Meridian 8. KB Elevation (ft): 15. Field/Pool(s): Top of Productive: Same .~¢,~... p~-~.v'~5 /~. ~o? 281 ft KB Pioneer Unit (610036) Horizon: Same /~' 9. Plug Back Depth (MD + Total Depth: Same TVD): 3562' KB MD 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD + 'I'VD): 16. Property Designation: Sec 14 Twn 17N Rng 2w 4050' KB MD Private Surface: x- 820' FNL y- 500' FEL Zone-4 11. Depth where SSSV Set: 17. Land Use Permit: TPI: x- Same y- Same Zone-4 N/A feet MD N/A TotalDepth: ×- Same y- Same Zone-4 19. Water Depth, if Offshore: 20. Thickness of 18. Directional Survey: Yes[~ No[] N/A feet MSL Permafrost: N/A 21. Logs Run: Cmt Bond Log 22. CASING, LINER AND CEMENTING RECORD CASING WT. SE'I-I'ING DEPTH MD SE'I-I'ING DEPTH TVD AMOUNT SIZE PER GRADE HOLE SIZE CEMENTING RECORD FT. TOP BOTTOM TOP BOTTOM PULLED 13-3/4 36 N/A 0 35 0 35 16 30 sx Concrete 9-5/8 36 J-55 0 677 0 677 12.25 84 bbls Class A 7 23 CF-50 0 4034 0 4034 8.75 142 bbls Class G 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) 3275-3284, 0.45" 23 gram, 45 holes ~ 5 spf 3202-3268, 0.45" 23 gram, 264 holes @ 4 spf 3-1/2 2651 2661 3184-3194, 0.45" 23 gram, 50 holes @ 5 spf 2862-2906, 0.45" 23 gram, 176 holes ~ 4 spf 2680-2734, 0.45" 23 gram, 216 holes (~ 4 spf 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 3194-3284 Borate x-link gel frac wi 110,000 20140 2862-2906 Borate x-link gel frac w/119,050 20/40 2680-2734 Borate x-link gel frac w/102,300 20~40 26. PRODUCTION TEST Date of First Production: N/A Method of Operation (Flowing, Gas Lift, etc.): Water Injection Date of Test: Hours Tested: Production for OiI-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: None None Test Period '~ N/A N/A NIA NIA Flow. Tubing Casing Pressure: Calulated ,.~ OiI-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-APl (corr): Press: None 24-Hour Rate N/A N/A N/A N/A Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas, or water (attach separate ~hbetl if'neceSsa~ry)Z' :' '": .~" Submit core chips; if none, state "none~ Form 10-407 Revised 4/2003 CONTINUED ON REVERSE SIDE ORIGINAL 28. None 29. FORMATION TESTS Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were GEOLOGIC MARKERS NAME I MD I TVD conducted, state "None". None 30. List of Attachments: Daily Completion Reports; Treatment Reports; all above listed logs 31. I hereby certify that the foregoing is_true and correct to the best of my knowledge. Contact Shane Ga.qliardi Printed Name~Ga.qlia~ ~/"~~. Title Petroleum Enqineer Signature ~ ." Phone 907-355-8569 Date 7/3/03 General: Item la: Item 4b: Item 8: Item 13: Item 20: Item 22: Item 23: Item 26: Item 27: Item 29: INSTRUCTIONS 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. 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. TPI (Top of Producing Interval). The Kelly Bushing elevation in feet above mean Iow Iow water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The APl number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). True vertical thickness. Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. 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). Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). If no cores taken, indicate "none". List all test information. If none, state "None". Form 10-407 Revised 4/2003 ORIGINAL 14 13 12 11 10 Current Well 1702-14CC APl -"-EOlt --I I 50-009'20016'00/ ~ I I1 QtrlQtr Sec 14 Twp 17N Rng 2w Size Weight Grade Thread Depth County Matanuska,Susitna State Alaska Casing 9-5/8 36 ppf J-55 ST&C 677 Field Pioneer Unit Country USA Casing 7 23 ppf CF-50 LT&C 4034 GL/KB 269/281 Tubing 3-1/2 9.3 J-55 8rd 2651 No. I Depth I LengthI ODI ID Description 1 3878 5 N/A N/A 3878-3883 perf 5 spf HCS 2 3834 4 N/A N/A 3834-3838 perf 5 spf HCS 3 3748 6 N/A N/A 3748-3754 perf 5 spf HCS 4 3718 6 N/A N/A 3718-3724 perf 5 spf HCS 5 3582 8 N/A N/A 3582-3590 perf 5 spf HCS 6 3520 2 N/A N/A Alpha Set 7" ClBP 7 3275 9 N/A N/A 3275-3284 perf 5 spf HCS 8 3202 66 N/A N/A 3202-3268 perf 4 spf 23 gram 0.45" premium 9 3184 10 N/A N/A 3184-3194 perf 5 spf HCS 10 2862 44 N/A N/A 2862-2906 perf 4 spf 23 gram 0.45" premium 11 2680 54 N/A N/A 2680-2734 perf 4 spf 23 gram 0.45" premium 12 2661 7.67 6.125 3 Arrowset ASI-X Plastic Coated Packer 13 2652 1.1 2-875 2.25 Standard seat nipple 14 2072 2.3 4.5 8.188 Gemco Md 715E stage collar (drilled out) PBTD 3945 Modified by STG 7/3/03 EVERGREEN Well Service Treatment Report 1702-14CC WDW Pioneer Field S2 T17 NR3W APl 50-009-20016-00 Mat-Su County ,Alaska 3 stage frac Job Started 29-May-03 Job Finished 30-May-03 Prepared for Evergreen Resources 14CC Treatment Report EVERGREEN Well Service Well Name: 1702-14CC WDW I I Date: 29-May-03 Customer: Ever~]reen ResourcesI Job Num: AK* SMARTSNVinFrac File - Formation: Tyonek Stage 1 Elap Av~l Cum. Sta~le Clean Blender Time Pressure Fluid Fluid Rate Conc. Prop Prop Comments/Fluid m~n psi bbl bbl bpm psa lbs type <-use 20/40 or 16/30 for auto-total Job started at 11:00 Safety Mtg 21 men 2,879 6.0 11.2 Water 3,118 6.0 217.0 14.0 BXL 3,135 223.0 133.0 14.2 1.0 5,000 20/40 BXL 3,172 356.0 81.0 19.6 2.0 10,000 20/40 BXL 3,113 437.0 92.0 19.3 3.0 11,000 20/40 Prop 3,030 529.0 128.0 15.4 4.0 11,000 20/40 Prop 2,999 657.0 96.0 13.9 5.0 23,000 20/40 Prop 2,850 753.0 177.0 14.4 6.0 45,000 20/40 Prop 2,782 930.0 18.0 13.3 8.0 5,000 20/40 Prop 2,878 948.0 123.0 19.3 Flush w/water 1,071.0 Stop 1,071.0 1,071.0 1,071.0 1,071.0 1,071.0 Summary Perfs: 3275-3284, 3202-3268, 3184-3194 Perf/Frac ClassificationNew Zone Shots/ft 4 Total Shots 340.0 Size" 0.39 Pumped Down Casing Pipe OD" 7 Pipe ID" 6.366 PipeTD' 3,520.0 Tubin~l Volume - Pipe Ibs/ft 23.0 Pipe bbl/ft 0.0394 Plu~l ~' Annulus bbl/ft - Tb~l OD" 2 7/8 Tb~] ID" 2.499 Tbg TD' Ann bbl Tb~l Ibs/ft 5.4 Tb~l bbl/ft 0.0061 Packer (~' Lowest cup - Frac Type 25# Borate XL Packer (~' Top cup - Fluid Volume bbl 1,071.0 Chemicals Total N2 Volume scf - scl Pumped scl Cooldown 135 usg BXL HCI conc 15% 85 usg diluted GB102 HCI Volume US~l - 1,650.0 ~lbs Guar 20/40 lbs 110,000 36.0 l lbs Biocide 16/30 lbs - - lbs Other 1 Total Propant 110,000 - gal Other 2 AIR bpm 15.0 Bkdn psi 5 min psi 2,548 ASTP psi 3,000 ISIP psi 2,562 10 min psi 2,533 BHP determined from: (F,S or E/ Post Job Frac Gradient 1.23 15 min psi 2,527 FracPro Comments: 956 psi on well when opened. Problem with pulses in line. Stopped on pad to fix reading on auger. 20 min shut in: 2523 psi Print Date: 9/2/2003, 2:52 PM 1 14CC Treatment Report, Stage 1 EVERGREEN Well Service Well Name: 1702-14CC WDW I I Date: 29-May-03 Customer: Evergreen ResourcesI Job Num: AK* SMARTS/WinFrac File l - Formation: Tyonek Stage 2 Elap Av~l Cum. Stage Clean Blender Time Pressure Fluid Fluid Rate Conc. Prop Prop Comments/Fluid m~n ps~ bbl bbl bpm psa lbs type <-use 20/40 or 16/30 for auto-total Job started at 19:43 Safety Mtg 19 men 2,550 3.6 5.0 Water 2,700 3.6 53.3 11.9 Gel 2,720 56.9 178.0 20.0 1,000 20/40 BXL Pad w/slug 2,791 234.9 137.0 21.8 0.8 4~800 20/40 Prop 2,654 371.9 100.0 18.5 1.7 7,100 20/40 Prop 2,545 471.9 95.0 17.4 2.5 10,300 20/40 Prop 2,454 566.9 95.0 16.6 3.7 14,600 20/40 Prop 2,311 661.9 223.0 16.0 4.9 45~500 20/40 Prop 2,169 884.9 81.0 15.5 5.7 19,500 20/40 Prop 2,186 965.9 58.0 15.0 6.7 16,250 20/40 Prop 2,349 1~023.9 112.0 19.0 Flush w/water 1,1 35.9 Stop 1,135.9 1,135.9 1,135.9 1,135.9 Summary Perfs: 2862-2906 Perf/Frac ClassificationNew Zone Shots/ft 4 TotaIShots 176.0 Size" 0.39 Pumped Down Casing Pipe OD" 7 Pipe ID" 6.366 PipeTD' 3,520.0 Tubing Volume Pipe Ibs/ft 23.0 Pipe bbl/ft 0.0394 Plug (~' 2,950.0 Annulus bbl/ft 0.0394 Tb~l OD" 0 Tb~l ID" Tb~l TD' - Ann bbl Tbg Ibs/ft 5.4 Tb~l bbl/ft Packer (~' - Lowest cup - Frac Type 25# Borate XL Packer (~' . Top cup - Fluid Volume bbl 1,135.9 Chemicals Total N2 Volume scl scl Pumped - scf Cooldown 150 usg BXL HCI conc 15% 80 usg diluted GB102 HCI Volume usg 1,050.0 lbs Guar 20/40 lbs 119,050 - lbs Biocide 16/30 lbs - lbs Other 1 Total Propant 119,050 - gal Other 2 AIR bpm 19.5 Bkdn psi 3,060 5 min psi 2,190 ASTP psi 2,450 ISIP psi 2,310 10 min psi 2,159 BHP determined from: /F,S or E) Post Job Frac Gradient 1.24 15 rain psi 2,137 FracPro Comments: 20 min shut in 2115 Print Date: 9/2/2003, 2:52 PM 1 14CC Treatment Report, Stage 2 EVERGREEN Well Service Well Name: 1702-14CC WDW I I Date: 30-May-03 Customer: Evergreen ResourcesI Job Num: AK* SMARTSNVinFrac File - Formation: Tyonek Stage 3 Elap Av~l Cum. Sta~le Clean Blender Time Pressure Fluid Fluid Rate Conc. Prop Prop Comments/Fluid mm ps~ bbl bbl bpm psa lbs type <-use 20/40 or 16/30 for auto-total Job started at 10:11 Safety Mtg 19 men 1,874 10.5 9.9 Water 2,014 10.5 68.7 22.0 Water 2,090 79.2 127.0 23.1 BXL Pad 2,124 206.2 116.0 21.9 1.1 4,300 20/40 Prop 2,056 322.2 103.0 19.4 1.9 7,600 20/40 Prop 1,939 425.2 165.0 18.5 3.1 20,600 20/40 Prop 1,904 590.2 122.0 17.9 4.0 20,200 20/40 Prop 1,858 712.2 100.0 17.3 5.1 21,100 20/40 Prop 1,794 812.2 50.0 17.0 6.1 12~500 20/40 Prop 1,788 862.2 48.0 16.1 7.7 16~000 20/40 Prop 1,875 910.2 103.5 21.1 Flush w/water 1,013.7 Stop 1~013.7 1~013.7 1,013.7 1,013.7 Summary Perfs: 2680-2734 Perf/Frac ClassificationNew Zone Shots/ft 4 Total Shots 216.0 Size" 0.39 Pumped Down Casing Pipe OD" 7 Pipe ID" 6.366 Pipe TD' 3,520.0 Tubing Volume - Pipe Ibs/ft 23.0 Pipe bbl/ft 0.0394 Plug (~' 2,820.0 Annulus bbl/ft 0.0313 Tbg OD" 2 7/8 Tbg ID" 2.499 Tbg TD' Ann bbl Tbg Ibs/ft 5.4 Tbg bbl/ft 0.0061 Packer (~' Lowest cup Frac Type 20# Borate XL Packer ~' Top cup Fluid Volume bbl 1,013.7 Chemicals Total N2 Volume scf - - scf Pumped scf Cooldown 123 usg BXL HCI conc 15% 68 usg diluted GB102 HCI Volume usg - 700.0 lbs Guar 20/40 lbs 102,300 :lbs Biocide 16/30 lbs - lbs Other 1 Total Propant 102,300 Igal Other 2 AIR bpm 22.0 Bkdn psi 3,201 5 min psi 1,837 ASTP psi 1,971 ISIP psi 1,869 10 min psi 1,823 BHP determined from: (F,S or E) Post Job Frac Gradient 1.13 15 min psi 1,811 FracPro Comments: 20 min psi- 1801 ISIP after breakdown - 1733 ISIP after injection - 1650 Print Date: 9/2/2003, 2:52 PM 1 14CC Treatment Report, Stage 3 ,? ".port,o 16 aog,n 05/31j03'. I ,,.,,, 1 I Daily Completion Report 5/31/2003 Pioneer Unit I1 .... JNW/NW J"0 J'~702-14cc J^,, J50-009-20016-00 I,!,,4 'i', 'l'W' I 1,",," lO~',,r,'o, lEvergreen Resources Alaska IF'"" I_P..!?neer I jCon~'.c,or J, JEws..Unit#9619 , JCurren!Activity IPrepare to pu,, WRP J'~r'0r~,,,l?~ PiiPare to ~quip. for inj. l :~5 3'00:00 IW;.,,Tot,, $)..J ..... I:' '::: JA,'ciden,(~,,,) JNO .. JLa,,tSaf,,ty,eeU,gDat, j.!:.:.: # I Start End Duration Activity 0600 0930 31/2 19 hr SICP 1400 psi. Open'ed well to flow back tank. Flowed 400 bbls LW. i.,.,,t ~.,,,,r.,~ ~,, 0930 1200 21/2 PU retre.'irg. ¢,~. f .... mr' :,.. 2 78" tbg and strap in hole. Found top of sand @ 2716'. Revursed circulated 96' of frac sand off W'R= Flu.3 '2' 28?.0 .',. fresh :',ater 12--00 "14~0 2 i/2 Unseat WRP & TOH. LB WRP. 1430 1630 2 PU retreiving head for WRP. TIH w/2 7/8" tbg. 1530 1630 1 Tag TOS @ 2885. Wash 65' of frac sand down to WRP @ 2950 w/fresh water. 1630 1745 1 1/4 TOH w/2 7/8" tbg & plug. LD plug. 1745 1830 3/4 Secure well. Clean up location SDON. ...... .. . · · i . . · . . COST ESTIMATE; · Western $20,000.00 Suprevision $600.00 Rig $2,700.00 .. ' ' ' Misc. $2,000.00 [:' $25,300.00 . ,. .. ~ Ve*' 1.0 ~t-118-28-99 Daily Completion Report i~..o~";'"'/,s",:' I",".'i' 1°5/3°/°3:'::': I~.. JWo, .JPioneer Unit k",,-a:~or "i ' l~W~'~"'~°Crew J,~u.o~,.o. ITr0ut ' I 1,o I~o=.~cc t...,,'1~'o-o.o~-~0o~-oo .. jo,.,a,o, JEvergreenResouroesA.aska JF'.i,',! I Jc....~,~l~ JPrepare to pull WRP J~,F .... ~J::: Prepare to equip, for inj. I ' ';'; :"::: ": : : We To~ $) ': I Start End Duration Activity ,~!~i! ............. i.i ........ !'; 5f;:~O:O..3.,.r,~pg,rt 2 n~ Page.. , ................... :. ................. :i:: ;...; 5':~Jn .5!P J,,837.psi,. !0~.ir! ,s, !P !8~3,..,P,~i.; .!~,..m!n,,. : ; ~J45 i215 t/2 bD well head isolation tool. Secure well and SDON. .=~ ~ :~ ..... 2:,¢! ................... ,;~'. i~½ ' ;11215 11500 23/4 RD EWS & MO frac equipment. · .. ...................... . . . . .... CO$1 FSII~ATI::; .. · ... .. · · ..... ........................... Ver 1,0 jjt-ll 8..28-99 Io5/25/o3 JWo, JPioneer Unit % 'lsw/sw [C0ntr~,ctor I IEWS Unit ¢¢9619 Daily Completion Report JEnu J5/25/2003::, I;1'4 I",:1 JRng J.2 IC°un~ [ CurrentA~vi~ Iprepare to run CBL ISupervisor ITrout Io,,,-a,or IEvergreen Resources Alaska IF,,,,,, I?i IMat-Sa I'b''' IAlaska IC''''"~ I Start I End Duration Activity 07'00 10930 1,1 ii, RU Cameron. Installed surface plug in mandrel in wellhead. Pressure test BOP to 3000 psi. Pulled mandrel. RU Patterson. 0930 :i'100 li!1/2 RU & ran GR CBL CCL from 3450' to 400'. ~ii~00 :!430 311/2 R]U & peri under full lubricator from 3202' to 3268' w/4 HPF using 4" HSC w/DP charges. :~30 i500 ~:/2 KD Patterson , ~.i ~,00 ;1530 ii;:,.;i :~ ~:~ EWS unit #402 to 7" csg to run injection test. Perfs broke down @ 2750 psi. Established injection rate of 5.4 aRM @ psi. :~i:ii:ii :~!;~!! ~mped 54 bbls of water. Dropped rate 1 BPM while monitoring pressure for 15 seconds and SD. ISIP 2320 psi 1530 1630 1 SI & monitor pressure for 1 hr. SIP after 1 hr. 1880 psi 1630 1745 1 1/4 Stad injection test. Established injection rate of 5.5 BPM @ 2600 psi. Pumped 420 bbls of l,resh water @ average rate of 5.5 BPM c, nd-A-verage-pressure-o~000-ps~d o1' h,jeuLion test, dropped injec[ion ra[e 1 UI'-'M for 3U seconds while monorting pressure 1745 2045 3 SI for 3 hrs and record pressure @ 1948 psi. , Pump shcedule report form unit # 402 to follow. 5-26-03 SD for holiday. 24 hr forecast. Prepare to frac. ,. COST ESTIMATE; Rig $2,500.00 :Patterson $ 31,750.00 ICameron $3,500.00 I Supervision $600.00 Misc. $1,500.00 .. Ver 1.0 Jjt-l/8-28-99 J~.por,.o J3i lin, Ch J05i25/03 :~: I(;~trlell JPi'oneer Unit Jco.,,ac~r J JEWS Unit ~619 Daily Completion Report 15/25/2oo3' I$,,.{T~Out I"° II*"' 15°-°°9-2°°18 114 I"".' I.'2 Ioou. C,,'o,tA~¥ity IPr. epare to run CBL 24hr Forec, Prepare to Frac Start End Duration , 01700 0,930 1i'! RU Cameron. Installed surface plug in mandrel in wellhead. Pressure test BOP to 3000 psi. Pulled mandrel. RU Patterson. Ib930 ;1i00 :I :~1/2 RU & ran GR CBL CCL from 3450' to 400'. ~i::~ 00 1t~30 3~/2 ~U & peri under full lubricator from 3202' to 3268' w/4 HPF using 4" HSC w/DP charges. I~!~30 ii~00 !:i2 ~iD Patterson i500 ;[530,. :.:.~ ::::~: ;~ :~U EWS unit #402 to 7" csg to run injection test. Perfs broke down @ 2750 psi. Established injection rate of 5.4 BPM @ psi. . ~:~.: ;i ~::ii~,i:i;ilil;;; .;~'i;ii ~Dmped 54 bbls of water. Dropped rate 1 BPM while monitoring pressure for 15 seconds and SD. ISIP 2320 psi 30 ;;! ':!i Si & monitor pressure for 1 hr. SIP after 1 hr. 1880 psi :!i~0 ii;~5 ~ :!iii/4 ~;!art injection test. Established injection rate of 5.5 BPM @ 2600 psi. Pumped 420 bbls of fresh water @ average rate of 5.~ BpM ~i~!:~;i_.~~' ...... ...... ';i~;ii!i ii'i!~il ~v~f--268e-ps~t-end-of~,-~jeu[;o~ [esi, d~Ul~Ped i.jucilon rate 1 BPM for 30 seconds while monortmg pressure 1745 2045 3 SI for 3 hrs and record pressure @ 1948 psi. Pump shcedule report form unit # 402 to follow. 5-26-03 SD for holiday. 24 hr forecast. Prepare to frac. . . · ;,. !;!i!iiii iii¢iiiiiiii; ~iig $2,500.00 ',ii!!iiii,;!;iii!il~ ::.:iiii~:i ¢:~tterson $31,750.00 Cameron $3,500.00 Supervision $600.00 Misc. $1,500.00 Var 1.0 iii-l/8-28-99 JR.~.or,.o J.31 J.eg,. Daily Completion Report JEnd Jwe,, JPioneer Unit ~ I: !::'!sw/sw Is~ ICOntractOr J IEWS Unit #9619 PO# I'!,;;j' IDa~ly Total{S) 15/24/2003: Is...r,,,.or ITr0ut J c-,'ent A~vit,j IRU Unit # 9619 :; IwellT°tal$ I 800:00.':;,;' :;::=:::' ':; INO J:;;;; Preparetoperf&frac. ,, Start End Duration 0800 0830 'i!2 Warm up equipment & gather connections. 8830 01900 1/2 :ROad unit #9619 to 1702-14CC 01900 i~000 ii:1 RU unit #9619 ~000 i':2oo 2? Nipple down well head. Install BOP. SDON ., _ __. · ,.. ; . .. ., ., COST ESTIMATE; · Rig Crew (Including travel & air far $5,800.00 Supervision $300.00 , Misc. $1,000.00 · Va' 1.0 jjt-l/8-28-99 Daily Completion Report Iw,,', Jt702-1400 INo [:. JAP, J50-009-20016-00 JOper, torlEvergreen Resources Alaska I~'e'a l~ioneer[ IQ'''~ 'lsw/sw Is", I~4 I~'* 117N I""' 12w Ic°u"ty IMat'su I'"" lA!asks 1%'¥usA I lpContra~r I I:EWS Un,t ~ 9~19 [Curr,r.t ActivE.".,' ]TIH ;'.'/Pscker 124~.- :l : Eva'ua'.ir.g for injoctica ....... o# I;?:ii!! pa,~,,o,a,(,. Iw''''°'''''''' I I 39.000.00 I*''-cE'°'''''' I~'''° I''":sa'''~;"~''''","'''' I Start End Duration Activity 0700 0530 1111/2. .P,:U 7" ASIx packer. TIH to 2500'. Blew hydraulic hose on rig: 0830 1!00 121/2 Gather pads, hydraul.ic .oil, and new hose. Made repairs. ::i:00 i~1i30 I;i':~2 ~iH to 3580'. Ran packer to remove any remaining ball sealers across perfs. Packer tight going through DV @ 2066' ii:.!30 ~230 1,11: PBTD 3554'. TOH w/tbg and pacl~er. ;~230 i:~00 12iii/2 BU Patterson. PU 7" CIBP. TIH. Set plug @ 3562'. RU dump bailer and top CIBP w/2 sx cement. New ~:;~::!i'.i!ilil :!i!i~:! ED Patterson. ~f~00 :;!.ii~30 ~i~1/2 ~.U 7" A$1x packer. TIH w/packer to 3457'. Set packer and test ClBP @ 3562' to 3000 psL Held OK Pulled !?iii!'~¢30 ~ i;ii!,,,, i:i!i:! ii;~iacker to 3140 and pressure test and pressure 2 7/8" x 7' annulus to 2500 psi for 10 min. Held OK. ~uu ~-/2~ T-OH-LB 2 7i8:: [b9 and packer. 5trip'ott BOP. Secure well. RD unit Cf 9619. Clean up around well. Prepare to move to 1702-15DA. No following .well service reports until completion starts. ii!iii i~iili!:ill i!ii!~!f,~'!'~i~:~' ;~ST ESTIMATE; Tool Man Supervision $600.00 Misc. #####cf# .. .. ... ISurnmary I iii;.ii!ii!: Ver 1.0 jif-l/8.-2~-99 I""p°""° l:..: j,eg,. 105!~0/03~:' Iw.,, . ,o I', Qt,Q~ IsW/sw Is.c 114 JTw~ I17N: Icontractor J'' IEWS Unit ~ 9619 "~" I:';;i ' 1'~;';"''o'''~' Daily Completion Report IE,,. J51!0i2003:~i iR,g 12W JCo-nty jCun'ent Activity iTOH w/T,BG, : .jwo,,,o,.,~, j j: ::$3;zoooo :::. P JMat-S. ' "'"'l,,.,. JAlaska I~ou.~, JUSA I 12,h,F ...... ti i S'.e..! ClBP and pressure test Start End Duration Activity !!~',',0,'0 ',.. 'i:~g0 ....... ~i:~. ," ...... ii" ' Lay dow, n,, PI.~s,!i~:,RU.un!t ~ 96!9r~ ~pg!,egg!,pm,~!.. " ...... , "..' ','ii 1800 2~1 oo 31 NipPle .UP BOP..RU Cameron and lubricate surface plug in tbg.hanger. Pressure test BOP to 2500 psi: Pulled sur~a.ce plug.. !2i'0'i~ 2'"3'45 ..... ~3i4 Strap out of hole w/2 7/8" tbg. Secure well & SDON. Pulled total' 0f 101 J{S °f2 ~/8" 'tbg; total of 3142'. ., .. . . .. · · . m I COST ESTIMATE; " Rig. $1,000.00 Cameron $1,500.00 .. ... Supervision $200.00 Misc. $1,000.00 $3,7OO.OO .. . · . Vet 1,0 Jil.ll 8-28-9g Daily Completion Report Re"°"N° I l,.o,, i05/10/03 ]End 15/10/2003 JSuper~isor ITrout ] We. ]1702-14CC ]No ] lAP' ]50-009-20016-00 ]Oper..or IEvergreen Resources Alaska I.,o,. IPioneer QtrlQtr ISW/SW ISeC 114 ITW I17N IRng 12W ]county ]Mat-Su Is~o ]Alaska ICountry IUSA Contractor I IEWS Unit # 9619 Icurrant ActIvIty ITOH w/TBG 12'hr F°rec"tISet ClBP and presiure test csg. I ,o, I p,,,,o.,,,,$3. oo.oo Iw''''o"',', I I IAccIdent(y/n) IN° ILastSafotyMeetlngDat" I Start End Duration Activity ,!_.7_0_0_ .... _!_8_00_ ........ 1_ ................................ L_a.y_d_o_w_n_.~./.9 s t i c~. R. _U_u_ n_ i_!... ~ _9_6_1_9 .__s_ D_O_ ! ~_q ui [~ m__e~: ............................ 1800 2100 3 __ ~i~e__up__BOP.. RU Cameron and lubricate surface p_lug in tb_g__ha.n_g_er.__P_ressure test BOP to 2500 psi. F~ulled surface plug. 2100 2345 23/_4 ......... Pulled total of 101 its of 2 7/8" tb~l~ total of 3142'. . ................................................ Cameron $1,500.00 . Supervision $200.00 Misc. $1,000.00 ................ . ....... . ,~ : ...................................... , ........ ,, , , Ver 1.0 jif-l/8-28.99 I~?o..o I j.o.,, lo5/11/o3 wo,, 11702.14cc I"° I IQt#~tr sW/sw Is" 1~4 ITw" 117N Daily Completion Report IEnd I~/~/~oo~ I"""''rv''°r ITr°ut I 1""' 150'009'20016'00 Io,.r.,o, lEvergreen Resources Alaska I~=,,,,~ IPioneer I I.ng 12W ]County IMdt'au Is~' IAlaska I°°""~'usA I Co,,,,or I Ewe Unit # 9619 ICur.o.t^ct,.,ty ITIH w/Packer ""r'or--,I Evaluating for injection .o, ..,,..o,.,,., I $ ,ooo.ooIw''''°''',', I I [No i Start End Duration Activity 0700 0830 11/2 ...... PU 7" ASlx packer. TIH to 2500'. Blew hydfaulic hose on rig._ 0..8_3_0 .......... !..1_00___-'--'...2.'~'_/'.2_._ G..athe___Lr ~rts,hyd_raulic oil, and new hose. Made repairs. :100 1130 1/2 TIH to 3580'. Ran packer to remove any remaining ball sealers across perfs. Packer tight going through BV @ 2066' .1_1_30 ........ i'230 1 _P.B_B_T_D 3____5_54'. TO_...__H w/~ and packer. 1230 1500 2 1/2 RU Patterson. PU 7" ClBP. TIH. Set plug @ 3562'. RU dump bailer and top ClBP w/2 sx cement. New RD Patterson. 1500 1730 2 1/2 PU 7" ASlx packer. TIH w/packer to.3457'.' Set packer and test ClBP ~ 3562' to 3000 psi. Held OK Pulled packer to 3140 and pressure test and pressure 2 7/8" x 7' annulus to 2500 psi for 10 min. Held OK. 1730 1900 1 1/2 TOH LB 2 7/8" tbg and packer. Strip off BOP. Secure well. RD unit # 9619. Clean up around well. Prepare to move to 1702-15DA. .......................... . No following well service reports until completion starts. · , COST ESTIMATE; ............ .,:; ......................... ?_~¢_n..~_ .............................................. $_3_,_9g_o._o_o ....................... .., Tool Man $1,000.00 ' ._S.u_pervision $600.00 Misc. $1,000.00 .............. :- .............. :" ............................ "'~ ....................................................... T~'b"6-~7(i~ ............................................................ , , Var 1,0 jjt-1 / 8-28-99 .e,or,.o J3 I"o,'" J05/24/03 Iwe. IPioneer Unit QtrlQtr I SW/SW ISec Daily Completion Report 15/ 4/2003 114 I'w~ I~ I""" I 2 [cou.t¥ Is.'o IAlaska /cou., lus^l Po~ I IDa''yT°ta'($' $7,100.00 Iw°''T°~'''' I I $19,800.00 IN° I Preparetoperf&frac.i Start End Duration 0800 0830 _ 1/2 Warm up_~quipmen, t_&__g, ather connections. .,. 0830 ,0900 1/2 Road unit #9619 to 1702-14CC 0900 1000 1 RU unit #9619 1000 1200 2 Nipple down well head. Install BOP. SDON , , .................. ~ .................................... COST ESTIMATE; ~,. ~~g~ travel & air far, $5,800.00 ~.uj3ervision $300.00 " Misc. $1,000.00 , , Ver 1.0 ~1-118-28-99 t"'.0""o 14 lB".I" 105/25/o3 wo, IPioneer Unit QtrlQtr sW/sw ISec Contractor I IEWS Unit #9619 Daily Completion Report IEnd 15/25/2003 14 ,wp 117 IRng I 2 Icou.ty IC urrent Activity Prepare to run CBL $39,850.00 wa Tot,,(,, I I $92.400.00 IMat-Su I~,,o IAlaska co,,,t~ USA 124hr Forecastl Prepare to Frac I F I"° I I I Start End Duration Activity .0_77.0 ..... 0_9..3.~ ........... .!_ ......................... R_U_ca__m_e..r_°_n_..l_n_st_all_e_d_S...u.d_a__c.e._pl._U~_Ln__.m_a_nd~r.e.?_.w__e_l!.h.e..ad_.: P__re~s.u.r_e t_?_t_BOP__t°__3_0..0..0_p.s_i:_P_u~!!_e_d_.~.a.n_~_re~l.:__R_U_._P?~.r?~ ......... 0930 1100 1 1/2 RU & ran GR CBL CCL from 3450' to 400'. 1100 1430 3 1/2 RU & perf under full lubricator from 3202' to 3268' w/4 H PF using 4" HSC w/DP charges. 1430 1500 1/2 RD Patterson ~5°0 1530 RU EWS unit #402 to 7" csg to run injection test. Perfs broke down @ 2750 psi. Established injection rate of 5.4 BPM @ psi. Pumped 54 bbls of water, Dropped rate 1 BPM.while monitoring_pressure for 15 seconds and SD. ISIP 2320 psi 1530 1630 1 SI & monitor pressure for 1 hr. SIP after 1 hr. 1880 psi 1630 1745 1 1/4 Start injection test. Established injection rate of 5.5 BPM @ 2600 psi. Pumped 420 bbls of fresh water @ average rate of 5.5 BPM and Average pressure of 2600 psi. At end of injection test, dropped injection rate 1 BPM for 30 seconds while monorting pressure .!_7_4_5_ ..... 2045 .................... 3 Sl.!~r_3 hrs and record pressure @ 1948 psi. P_u~ shcedule report form unit # 402 to follow. 5'26-03 SD for holiday. 24 hr forecast. Prepare to frac. , · , ; , , , , COST ESTIMATE; ..................................................................... ,p,a_t.t_eL§.o..g ........................................................... $_31,7._._59 , Cameron $3,500.00 _ ...................................... ~..u_pervision $600,00 ................ ........... ..................Misc, $1,500,00 , , , , , ................... 'iUmmary ~ ..... Ver 1.0 it-l/8-28-99 Daily Completion Report Report No ] IBegin 105/30/03 End 15/30/2003 lSupervl~.Or Trout wo,, 11702.14CC .o 4 AP, 150-009-20016-00 Iopor"'o" IEvergreenResourcesAlaskaJF,.,,~ JPioneer QtrlQt, NW/NW Is- 1~4 mw, 17 Rng J 2 Ico,,,ty IMat. Su is=, IAlaska Jcou.~ USA ContractorEWS Frac Crew cun'ent Activity Prepare to frac 3rd Stage 2'"'r For'o'tI Prepare to Clean out ,o,I o.,,,,o,.,,,, s , oo.oow.,,o,.,,,, I I,o I # I Start End Duration Activity 0700 0715 1/4 RU EWS to 7" cs.g: Presseur test to 2680.psi. Held OK. .0_71__5_ ...... 9.93__0 ...... ..2.1/~4 .......................... ~_U_ _P_a_tte r___s o__n_&_~e_~ U n___d e_r f__u I_1 [u_b r_i_c a~t o_r. f r~ _m_ ~ .6_8.c).'- t_o_ _2_7 3_ 4__' 4__ ~H_P_F:_ .u..s i_ .n~g..4 '_' _H_S_C_ .W/D__p _c_h._a r_ge_s:_R.D_ _p_a_tt.e r__s_ o_n__ ..... 0930 1000 1/2 Install well head isolation tool. .!..0_0...0. ........ 10. !._5- ........ 1_!4_ ...................... . ,R. .U .. _E __W_ S_ fr_a_ c__c..re_w_._p_[_e_s_s_u_r.e_t_es__t_fg~._!ra__c t__o_4_ .7.~_O__p~ i__, ._!._0.!_5_ ............ 10_45__ .... _1_(2~ ...................... Broke down perfs 2680' to 2734' @_3_2.,o_o_p_s.!,._R_a,_n..p_.r..e.;_f_!~a.c~_._p.?..p.,i.~n_t. ff. St: .1_075 ..... 11.4_5 ....... ! .!.)_P..u_...rn_ ,p_e.d_.p_.r~-.fr_.a~ .!n_j_es!i?...t_es_t_..!§). P_._!.6~.0_gsj~: .................................................................... _2),ZP u_m p_e_d_t_2 7_b_.b. Ls ..B_X_L,..P?.d_...¢~,3__:.t. ~2, _M: ............................................................. 3_),_Pumped 116 bbls BXL w/1,1 ppg_20~40 sand..~_ 21,9 BPM, ................................................... 4,.) _P.u_m_p_e_d. ! 0_~3..b_b.!_s. B._~X_L ._W,/_l:,..9_p. ~.g...2_0/4_0_s_a n_~d .@~19,__4_B P__M_. ........................................................................... '.7.)_P_u_mpe__d~.~0__b.b_ls_~_X~ w_~/5_..l_.p_p_.g_ 2_0/_4..0_~an__d_@__l~.~_B~.- .............. ~) pumped 50 bbls 9XL w/6.1 ppg 20/40 sand @ B_PM__:. ................................................................................ ..................... .9~ Pumped 48 bbls BXL w, 7.7 ppg 20/40 sand ~ 16.1 BPM. 1_~ Flushed w/104 bbls water. : .................................................................... ,,EWES .............................................................. .$7__5 0_0_0..,.0.0- , , ............................................................ S..g., ,.p,.r.e,y.i_s?_ ........................................................................ $6__0~:_~.0~. ........................................................ ~!s_c, ............................................................................................... ~_,.500:99_ $79,6oo,oo , .................................. Notes Vet 1.0,~t-1/8-28-99 JReport.o J5 Begin J05/30/03 we,, JPioneer Unit Otrletr NW/NW Jsec Contractor J JEWS Frac Crew Daily Completion Report JEod J5/30/2003 JNo J1702-14CC JAP~ J50-009-20016-00 114 I'w" I17 I~"° I 2 Jcounty JCurrent Activity Prepare to pull WRP WoTota(,) I I JsupervIsor JTrout O.er. or JEvergreen ResourcesA,aska F,o,d JPioneer JMat-Su Is'.. JAlaska co..w IUSA J24hr FO~ J Prepare to equip, for inj. JAccldent (y,n) JNo JLast Safe~ M.,ng Date J ~ Start End Duration Activity 5.:30_:~a_ge. 5 min SiP 1837_psi, lOmin SiP '1823 psi, 15 min SIP 18~1,20 min SIP 180~. 1145 1215 1/2 LD well head isolation tool. Secure well and SDON. .!.2_1_ 5_ ......... 15_07 .......... .2_.3_/_4- ................................... _.R.~._ .E_.W_S_.~ _~_.O_f[a_c.__e.q Uip_m_e_n_t: ......................................................................................................................................................................................... ,, ¢05T F:STI~ATF:; , , .:, ,, , , , ......... Isummary J Vet 1.0 JJt-l/8-28-99 Daily Completion Report [..p°rtNo 16 a,,,l. 105/31/03 IE"c~ 5/31/2003 I ]Supervisor ITrout w.,, IPioneer Unit I.o l~?02-~4cc I^P, 150-009-20016-00 opor..or IEvergreen Resources Alaska F,.,a IPioneer I~,~ NW/NW Is~ 14 ITw I17 ""0 I 2 Ico""ty IMat-Su Is-. IAlaska co.,,,,¥ IU.SA l'Co.,r, orI I WS Unit # 9619CurrentA~v,t~ IPrepare to pull WRP 124hrF ...... tI Prepare to equip, for inj. PO# I IDaily TOtal <$) $25,300.00 I I I $117,700.00 IAccldent(y/a) INo ILastSafetyMeetlngOata I #- Start End Duration Activity 0600 0930 3 1/2 19 hr SICP 1400 psi. Opened well to flow back tank. Flowed 400 bbls LW, 0930 1200 2 1/2 PU retreving head for WRP on 2 78" tbg and strap in hole. Found top of sand @ 2716'. Revursed circulated 96' of frac sand off WRP plug @ 2820 w/fresh water, 1200 1430 2 1/2 Unseat WRP & TOH. LD WRP. 1430 1630 2 PU retreiving head for WRP. TIH w/2 7/8" tbg. 1530 1630 1 Tag TOS @ 2885. Wash 65' of frac sand down to WRP @ 2950 w/fresh water. 1630 1745 1 1/4 TOH w/2 7/8" tbg & plug. LD plug. 1745 1830 '3/4 Secure well, Clean up location SDON. , COST ESTIMATE; ................................................. Western $20,000.00 ,L_ .................................................. .S~u_prevision $600.00 ~ $2,700.00 , , ,, , ...... Var 1.0jjt-1 / 8-28.99 Daily Completion Report ReportNo 17 IBegin 106/01/03 End !6/1/2003 ISupervisOr Imr°ut wo,, IPioneer Unit I.o 1~?02-~400 l^P, 150-009-20016 IO.'~"'or IEvergreen Resources Alaska F,.,d IPioneer OtrlQtr NW/NW Is~ 114 ITw 117 R., I 2 Co.nty Is"" IAlaska co..~ USA Co.,=,or EWS Unit#9619 curro.,A~,~]m~H w/2 7/8" tbg to Tag mos. I=,,r,o...,IPrepare to Equip. for Inj. ,o, D.,,,,o.,,,, $s,100.00 Iw°'''°"'''' I I $123,800.00 IN° I"''s'''~""''"""'ta I 6-1-03 Start End Duration 0630 0730 1 11 1/2 hr SICP 1000 psi. Opened well to flow back tank. Flowed 150 bbls LW in 1 hr. 0730 0900 1 1/2 PU retrieving head without grapples. TIH w/2 7/8" tbg, Tag TOS @ 3369', Reverse circulated 175' of frac sand out of 7" csg 0900 1130 21/2 down to 3544'. Circulated hole w/EWS unit # 402 using fresh water. 1130 1300 1 1/2 'TOH LD 2 7/~-;~'1~-~' 1300 1330 1/2 Changed rams in BOP to 3 1/2". .!..3.~.0_ ........... 173~0 ..... _4__ ......................... ?__7_" A__S.~l_x_._p. ack___e r_o_n_3_l/_2" t Dg____:_TI_H_w_ !t~_&_..p_a_c_k_e_r_as__!.ollo___w.~.- 1-7 1/16" x 3 1/2" tgb hanger mandrel ,75 90 its 3 1/2" 9.3# EUE J-55 tbg 2651,42 1- 2 7/8" x 2,250 seating nipple 1,10 1-2 7/8" EUE x 3 1/2" EUE XO ,50 1-ASlx 2 7/8"x 7" packer 7,67 2661,44 , 1730 1830 1 RU EWS unit # 402 to 3 1/2"x 7" annulus and pumped 100 bbls packer fluid containing 1 drum packer fluid. 183o t9~'~- ...... ~ ...................... , ?..3..~ ........... 20.0..0_ ........ , , COST ESTIMATE; :~ $2 500 oo _: ................................................................................................ ~!_sc_,. $6,100.00 : ............................................................. Vet 1,0 lit-l/8-28-99 I.o.o..o 18 I"o.'n Io6/o2/03 w~, IPioneer Unit Qtr/~tr NW/NW Daily Completion Report lEnd 6/2/2003 Contractor I IEWS Unit# 9619 PO# I IDaily T°tal (s) INo 11702-14CC JAPI 150-009-20016 Current Activity Prepare to set packer $1,600,00 Wa" T°t'l (s) I I $125,400,00 Icou. IAlaskaIcou.,~ IUSAI 124hr ForecastI Prepare to equip for inj. ] INo I'-,s.,oty M-ti., Data I 6-02-03 I Start End Duration 0__530_.~___ _0_60__~_0 __ 1/2 R_e_~,'_o_"_rin s og.~_~_~b._g_h_a_n_ger, 10 hr SICP 400 psi, O.Dened to tank and bled off [)ressure, 0600 0700 1 ...S. et__packer w/15 p_t_s c_om_~, r_e_s_sion, KB bottom of packer ~ 2671'. Seatin._g__njpp_l_e_@. 2662' ,,07,00 ,0,.800 1 Nipple down BOP. Install adaptor flange & tree valve. 0800 0830 1/2 RU EWS unit # 402 & reassure test 3 1/2" x 7" annulus to 1500 psi for 10 min. Held OK. _0.8_3~ ........ 09,3_0- ....... 1 .......................... RD EWS unit # 9619 & unit # 402. Clean up location. Secure well & MO WSU. ............................................................... ~.N_,.o_ _w_e I~!.,.r_e_p_o~.s_?_t i_I !.n_ j_e_c._t, i_o_n_t~.s_t_a r__e _r u_ n_. , , , COST ESTIMATE; '. R_~ $500.00 Supervision $600.00 Misc. $500.00 . .. $1,600.00 , ..... Ver 1,0Jif-l/8-28-99 Daily Completion Report lEnd 16/17/03 Supervisor ITroutJGagliardi I Field IPioneer I Country USA ' I I I Operator I Evergreen Resources Alaska IMat-Su Is,.,, IAlaska I"", Forecalt I Injection Test IA=cld°nt(''") IN° ILa"t saf°~ M°°tln~ Data I ,o, I IDa''yT°ta'($) I $2,400.00 IWe"Tota'(,) I I$127'800'00 Start End Duration Activity !,300 :1400 1 _ M,,,IRU EWS cmt unit ~02. Pressure annulus to 1500 psi; held for 30 minutes. Witnessed by AOGCC inspector Chuck Scheve. 1400 RDMO EWS to 1702-15DA for MIT. ........ ---- , , , ¢05T ESTIMATE; ,, EWS $1,000.00 ........... ! ....... ., .... Water $300.00 :- : : SUpervision $600.00 .... Misc. $500.00 Total $2,400.00 , , Summary I- .......... Ver 1,0jJt-l/8-28-99 RESOURCES (ALASKA) CORP. A Subsidiary of Evergreen Resources, Inc. July 9,2003 Winton Aubert Petroleum Engineer Alaska Oil and Gas Conservation Commission (AOGCC) 333 West 7th Ave. #100 Anchorage, AK 99501-3539 RE: Completion Reports (Form 10-407) Pioneer Unit - DL Smith #1, Stromberg #2, RL Smith #3, Cornhusker #4, Cook #1 and 1702-14CC Dear Mr. Aubert: Attached are the 10-407 forms for the following wells, listed with the wells are the corresponding 10-403 numbers issued for the completions. The wells are currently producing, but are still in the testing phase. All gas is being vented at this time. Well 10-403 # RL Smith- 303-096 DL Smith- 303-109 Stromberg- 303-095 Cornhusker- 303-099 Cook - 303-098 If you have any questions, please feel free to contact me at 907-355-8569 or shaneg(¢evergreengas.com. Sincerely, Shane Gagliardi Petroleum Engineer ORIGINAL 1075 Check Street, Suite 202 · Wasilla AK 99654 P.O. Box 871845 · Wasilla, AK 99687 · TEL907.357.8130 · FAX907.357.8340 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Randy Ruedrich '"~ Commissioner '~!~/~ THRU: Jim Regg ¥.~,,(2~. P.I. Supervisor / FROM: Chuck Scheve Petroleum Inspector NON- CONFIDENTIAL DATE: June 17, 2003 SUBJECT: Mechanical Integrity Test Evergreen Pioneer Unit Well 11702-15DAI P.T.D.I 99-64I Notes: Well 11702-14CCI P.T.D. ] 99-65I 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. I Type lnj.I sI 12740 I Tubingl 00 I,ntervall I I Type testI P I Testpsil ~500 ICasingI 25 I ~S601 ~SSOI ~560I P/F I __PI I Type testI P I Testpsil ~SOOICasingI 0 1'~6OOl ~6OOl lSOOl P/F I p_PI I IType Ini. Type test Type test Type Inj. 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 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 Attachments: Number of Failures: 0 Total Time during tests: 3 hours cc: MIT report form 5/12/00 L.G. 2003-0617_MIT_Pioneer_15DA_cs.xls 7/9/2003 May 15, 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: 10-403 Sundry Notice Hydraulic Fracture Treatment Evergreen Pioneer Unit 1702-14CC / / / APl: 50-009-20016-00 Permit: 99-65 NW of Section 14 Twn 17 North Rng 2 West Matanuska Susitna Borough, Alaska Dear Commissioners Palin, Ruederich and Seamount, Evergreen Resources Alaska Corporation submits the following 10-403 to perforate and then hydraulically fracture the subject well. We plan to utilize this wellbore as a water injector well under Injection order 20. Evergreen hopes to begin operations on May 27, 20O3. Thank you for your help. Please contact me if you have any questions. Sincerely, Evergreen ResouJil:es (Alaska) Corp ' Z Alaska Projects Manager Attachments $CANNE~ JU~ 1 ~ 2003 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT FOR SUNDRY APPROVALS 1. Type of Request Abandon ~ Suspend ~;! Operation Shutdown After Casing 7£ Repair Well ~;;.~Plugging Change Approved Program E1 Pull Tubing ~.--.q Variance Re-enter suspended well Time extension [] Perforate IF'~ ~ Stimulate ~.; Other 2. Name of Operator Evergreen Resources Alaska 5. Type of Well Development '.-: Exploratory [] 3. Address: P.O. Box 871845 Stratigraphic ~ Wasilla, AK 99687 Service '~ 4. Location of well at surface: NW of Section 14 Twn 17 North Rng 2 West, Seward Meridian 500 FWL and 820 FSL OF Section At top of productive interval: Same At effective depth: Same Total depth: Same 6. Datum elevation (DF or KB): 281 tt KB (12 ft AGL) 7. Unit or Property Name: Pioneer Unit 8. Well number: 1702-t4CC /' 9. Permit number: 99-65 / 10. APl Number. 50-009-20016-00 11. Field and Pool: Pioneer 12. Present well condition summary Total depth: Measured 4034 feet Plugs (measured) true vertical feet CIBP 3,520 ft wi2 sx cement Effective depth: Measured 4~34 feet Junk (measured) none true vertical feet Casing: Length Size Cemented Measured Depth True vertical depth Structural Conductor 55' 13-318" 55' Surface 665' 9-518" 400 sx 15.8 ppg Class G, Circ to Surface 665' Intermediate Production 4034' 7" Below DV: 310 sx, 15.8 ppg Class G, Above DV 4034'-- / 268 sx t2.5 ppg class G circulated to surface. Existing: Below CIBP: 3878-83,3834-38,3748-54,3718-24,3582-90, Above: ~I2¥5-84,3184-94,.ItKB Proposed: 3,202-3,268, 2,866 0 2,900, 2,680-2-734 ff KB (i..~ Liner Perforation depth: Measured True vertical Tubing (size, grade, and measured depth) Existing: Below ClBP: 3878-83,3834-38,3748-54,3718-24,3582-90, Above: 3275-84,3184-94 ft KB Proposed: .3~202-3~268, 2~866 0 2~900, 2~680-2-734 It KB 3144 It, 2-718", 6.7 ppf, K-55, 8 round, EUE Packers and SSSV (type and measured depth) none 13. Attachments: Description Summary of Proposal [] Detailed Operations Program [] BOP Sketch [] 14. Estimated date for commencing operation S,,umtay~ay 20 2003 16. If proposal was verbally approved Name of approver Date Approved 17. I hereby certify, that the ~regoing is true and correct to the best of my knowledge. ~/,~~~ Title Alaska Projects Manager Signed 15. Status of well classification as: Oil D Gas [] Suspended D Date May 13, 2003 Service FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Approval No. ~ o~_'-5 --- / ~-! ~ Plug integri~ ~ BOP test ~ Lo~tion clearan~ ~ Mechanical integri~ test u Subsequent fo~ required 10-~ ~ Approved by o~er of the Commission ~ ~ ~ Commissioner Date r//~/~ ,F~.3~ Rev 06/1~'~ ~ " ~ ~ ~ ~BMIT IN TRIPLICATE ECEIVED MAY 1 5 2003 SCANNED JUN 1 2 2003 ORIGINAL Alaska 0il & Gas Cons. Commission Anchorage =V=I GE==N RESOURCES IALASKA) CORP. ,~ $,~5~..,~,.a¢,. c,~ E~e;o,ee,~ ~e.~,'~'~;'s, Program Summary Pioneer Unit 1702-14CC APl: 50-009-20016-00 Permit: 99-65 NW of Section 14 Twn 17 North Rng 2 West The subject well was spud by Ocean Energy on August 28, 1998 and drilling was completed on September 14, 1998. The well reached a total depth of 4050 feet, logs were run and 7", 23 ppf casing was run and cemented. On September 19, 1999, the well completion program commenced and consisted of perforating the Tyonek formation in the intervals below. These perforations were broken down with 349 bbls of 2% KCI and balls at 4.5 to 5.5 bPm. The well was swabbed for 3 days and recovered 108 bbls of load with no gas shows. On May 8 and 9, 2003, Evergreen pulled the tubing, placed a cast iron bridge plug at 3,520 ft KB and placed 2 sacks of cement on top of the plug. With tubing and packer, the plug was successfully pressure tested to 3,000 psi. The packer was reset above the perforations and the well the annulus was pressure tested to 2,500 psi and held. This work was done to test the casing and to isolate zones downhole. Evergreen now proposes to perforate sandstones within the wellbore, hydraulically fracture stimulate those zones and to utilize the wellbore as a water injector. Form 10- 403 show the existing and proposed perforations. The table below summarizes the three stage fracture treatment we currently plan for the subject well. Sand volumes will change as a result of on-site analysis of the relevant rock properties. ~'" Proposed Perforations & Fracture Treatment Stage Perforations Height Frac Description 1 3,275-84, 3,202-68, 3,184-94 85' +~-200,000 lbs 20~40 borate x-link 2 2,866 - 2,900 34' +/-150,000 lbs 20~40 borate x-link 3 2,680 - 2,734 54' +~-200,000 lbs 20/40 borate x-link Evergreen will utilize its own frac fleet, cement pump, single-double work over rig and water trucks currently residing in Wasilla for this operation. As specified in 20 AAC 25.280 (b)(4), fresh water will be used to control the well. A high pressure cementing or fracturing pump will be on location to kill the well if necessary. We do not expect well control issues on this 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 (3,275 ft x 0.435 psi/fi) or 1,425 psig. We plan on using 3,000 psi BOPE. Regulation ExcePtions 20 AAC 25.285: Evergreen requests that our manual BOPEs, as illustrated on the next two pages be acceptable for the frac and the clean-out operations. 20 AAC 25.287: Evergreen requests that our Fullbore lubricator and spool on top of the Demco Frac Valve is acceptable. 20 AAC 25.066: Evergreen requests that the gas detection provisions provided in this section be waived if this can be done without 30-day public notice. We have experience with this wellbore and have reviewed the well records. No gas has come to surface. If ._~ the 30 day public notice is required, then Evergreen will run gas detection equipment. Street: 1075 Check Street, Suite 202 Wasilla, AK 99654 Mailing: P.O. Box 871845 Wasilla AK 99677 Tel 907-357-8130 Fax 907-357-8340 www. EvergreenGas.com =V=I GR==N RESOURCES (ALASKA) CORP. BOP DETAIL BOP DETAIL FOR WORKOVER OPERA TIONS A schematic of Evergreen's BOPE for workover operations is shown in the adjacent figure and detailed in the table below. We will utilize this set-up after the fracture treatment to retrieve (via tubing) the bridge plugs and to clean-out sand in the wellbore. Here we propose using 3,000 psi, 7-1/16 inch BOPE manually operated system. The BOP is attached to the 9-5/8" casing head which is also our spool in this operation. ) a Strip Head I I I To Pump Wellhead To Tank BOPE Size Psi No Item Manufacturer (in) Rating 1 Valve FMC or equivalent 2 3,000 2 Valve FMC or equivalent 2 3,000 3 Valve FMC or equivalent 2 3,000 4 Valve FMC or equivalent 2 3,000 5 Tubinghead & Spool Wellhead Inc 7"x 2-7~8 3,000 6 BOP: Blind Ram Townsend Manual Operated 7-1/16 3,000 7 BOP: Pipe Ram Townsend Manual Operated 7-1/16 3,000 8 Stripping Head High Tech Tools 7-1/16 3,000 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 3,000 psi and the insert rubber, manufactured by Triple M (Odessa, TX), designed for 2-7/8" tubing, 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 knowledge with wellbores in this field. Street: 1075 Check Street, Suite 202 Wasllla, AK 99654 Mailing: P.O. Box 871845 Wasllla AK 99677 Tel 907.357-8130 Fax 907-357-8340 www. EvergreenGas.com RESOURCES (ALASKA) CORP. Blow Out Prevention Equipment for Wireline 0 Shown in the adjacent figure is a schematic of our proposed set-up for shooting perforations and setting plugs via wireline. 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 Ib/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. =erations · ~ J PlpeRams J ~ J BIIndRams J I I I To Pump [~~ 5 ' Wellhead To 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 20.01 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 Manual Operated. 7-1/16 3,000 2001 7 BOP: Pipe Ram Townsend Manual Operated 7-1/16 3,000 2001 8 Full bore lubricator Patterson Wireline 5-1/2 3,000 1999(?) Street: 1075 Check Street, Suite 202 Wasilla, AK 99654 Mailing: P.O. Box 871845 Wasilla AK 99677 Tel 907-357-8130 Fax 907-357-8340 www. EvergreenGas,com RESOURCES (ALASKA) CORP, PROPOSED PROCEDURE Pioneer Unit 1702-14CC APl: 50-009-20016-00 Permit: 99-65 NW of Section 14 Twn 17 North Rng 2 West Objective: Perforate and then hydraulically fracture stimulate the Tyonek formation down casing and place on line as a water injection well. Elevations: Ground' 269 ft Kelly Busing: 281 ft (12 ft AGL) Tubulars- Surface: 677' KB, 9-5/8", 36 ppf, cement circ to surface Production: 4034' KB, 23.0 ppf, CF-50, ST&C, 8 round, PBTD @ 3520' Tubing: 3,144 ft KB, 2-7/8", 6.4 ppf, J-55, 8 rd, EUE, limited service History: Subject well was spud in August 1998. The well was completed in September of that same year by drilling out DV tool at 2072, running scraper, perforating several seams in the Tyonek, breaking those same perforations down with 346 bbl 2% KCL at 5.5 bpm using 1.3 sg balls, and then swabbing the well. No gas produced and 108 bbls of load was recovered. No gas was reported. The well was left with 101 joints (3,144 feet of 2-7/8" tubing). Cast Iron Bridge Plug at 3,520 ft KB placed on May/' 8, 2003. Pressure tested plug and casing above upper most perforation. All pressure tests passed. One hundred one joints of 2-7/8" tubing is laid down on location. Preparation: 1. AOGCC: Contact AOGCC (907-279-1433), Winton Aubert, 24 hours prior to /' operations. 2. Frac Tanks: Three clean 500 bbl frac tanks with manifolds. Two tanks will have gel and one tank will have fresh city water. 3. Flow back Tank: One open flowback tank on 40 ft trailer. 4. Water: Water must have biocide in it. An equivalent 4% KCi solution will be added to all water pumped/injected into well bore. 5. Water Truck: Evergreen water trucks in Wasilla using DJ Excavation personnel. 6. Pumping Services: Evergreen Well Service International Frac Fleet 7. Workover Rig: Evergreen Well Service Rig No. 1696 8. Wireline Operations: Patterson Wireline. Scott Allen (907-354-4529). 9, Haul Tubing: 101 joints already on location - to be used to get plugs. Spills' 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 tank will be in place at all times. Duck Ponds to be placed under all vehicles. Ti~lht Hole: No information from this well may be shared with anyone outside of Evergreen Resources. Street: 1075 Check Street, Suite 202 Wasilla, AK 99654 Mailing: P,O, Box 871845 Wasllla AK 99677 Tel 907-357-8130 Fax 907-357-8340 www. EvergreenGas.com PROPOSED PROCEDURE (CONTINUED) 1702-14CC Personnel: Evergreen Resources Office: Engineer: Shane Gagliardi Tool Pusher: Jerry Trout AK Proj Manager John Tanigawa Accommodations: Fax: 907-357-8130 907-357-8340 907-355-8569 907-354-4529/4394 907-841-0000 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: Houston Lodge 907-892-6808 Patterson Wireline: Big Lake Motel 907-892-7976 I~ap to 1702-14CC Well · This well is located on Vine Road, 1,7 miles south of the Parks Highway. This well is located immediately east of the 1702~15DA injection facility on the lease road. Tubing Casing Annul_~.~ Casing and Tubing Data Strengths taken to 100% for Tubing and 100% of Casing Size I Weightl ID [-Drift I Collapse I Burst i Yield I dapacity I Capacity I (in) (ppf) (in)_~ (in) (psi) _~psi) I (klbs) Sbls/ft Ft/bbl ] 2-7/8 ! 6~4 2.441'-~2.347 7,680 7,2601 72 0.~)5794 ~ 7 [ 23- 6.366~&151 3,27-0 4,360 ~4 0.03936 25.4021 Street: 875 Check S~eet Suite 202 Wa~lla Al( 9~854 Mailng: PO Box 871845 Wasilla AK 99677 Tel 907-357 8130 Fax 907857 8340 w,'~v E ve~gre er~Ga a corn RESOURCES (ALASKA) CORP, ,~ ~q.L,.'"~'~ ~,",.' <~ £ve,o .-e~ ~e_~,...~.e~, -,.lc Office: PROPOSED PROCEDURE (CONTINUED) PIONEER 1702-14CC 1. MIRU Evergreen Rig No. 1696 and Evergreen Well Service (two 10,000 psi triplex pump trucks, blender, two sand bins, three 500 bbl frac tanks w/city H20. 2. NU & Test 3000 lb manual BOP, Stripping Head and spool. RU flow-back lines to tanks. 3. MIRU Patterson Wireline. NU Fullbore lubricator. // 4. Perforate 3,202 to 3,268 ft KB with 23 gr, 0.48", premium shape charges on 4" guns at 4 shots/foot. RD Patterson Wireline. 5. Perform pre-injection test to determine leak-off coefficient and closure stress. 6. STAGE 1: RU Evergreen Well Service. Fracture Stimulate interval down casing with 20-25 lb cross linked gel and 200,000 lbs of 20/40 proppant. Maximum Surface treating pressure 3,000 psi. Utilize FRACPRO to design treatment after pre-injection tests. Obtain at least 20 minutes of fall-off data after frac is pumped. 7. Flow well to tank until zero psi at tank. RD Evergreen Well Service. 8. RU Patterson Wireline. Under full-bore lubricator, set RBP at +/- 2,910 ft KB.,~,/,' Perforate 2,866 to 2,900 ft KB with 23 gr, 0.48", premium shape charges'on-, / guns at 4 shots/foot. RD Patterson. 9. STAGE 2: Fracture Stimulate 2"d zone with 20-25 lb borate' cross linked gel and 150, 000 lbs of 20/40 proppant. Maximum Surface treating pressure 3,000 psi. Utilize FRACPRO to design treatment after pre-injection tests. Obtain at least 20 minutes of fall-off data after frac is pumped. 10. Flow back to tank. RD Evergreen Well Service. 11. RU Patterson Wireline. Under fullbore lubricator, set RBP at +/-2,770 ft KB./' Perforate 2,680 to 3,7~ K~L,~,~h 23 gr, 0.48", premium shape charges on 4" guns at 4 shots/foot."RDMO'Pa{~'~rson. 12. STAGE 3: Fracture Stimulate 3rd zone with 20-25 lb borate cross linked gel and 200,000 lbs of 20/40 proppant. Maximum Surface treating pressure 3,000 psi. RD Evergreen Well Service. 13.$WIFN. 14. RDMO Evergreen Well Service. 15. RU Evergreen Cement Truck and flow-back tank, including kill line and choke line. 16. Bleed well pressure to flow-back tank. 17. RIH with retrieving head on 2-7/8" tubing. Circulate sand off of RBP. Retrieve RBPs and clean hole to PBTD at 3,520 ft KB. 18. Clean-out hole to TD 19. Set packer at 2,520 ft KB (good quality cement here). 20. Pressure test tubing. 21. Test Injectivity of well using frac pumps and 4% KCl fluid. 22. If well accepts fluid, then perform tasks to place well. on injection (MIT, step-rate injection tests). Record test results to determine formation fracture pressure. 23. Circulate packer fluid if well will be placed on line. 24. Clean Location. ./' 25. RDMO 26. Turn well over to operations for water injection well hook-up, 1075 Check Street, Suite 202 Wasilla, AK 99654 Mail: P.O. Box 871845 Wasilla, AK 99687 Te1:907-357-8130 Fax:907-357-8340 vvww. EvergreenGas.com Everqreen Resources Alaska Corp Pioneer Unit t702 4CC Section 14 Township 17 North Range 2 West AP~: 50-009-20016 13-3/8' Conductor Casing 13.375", 68 ppf, 0-55 ft KB 9-5/8" Surface Casing 9-5/8", 36 ppf, 0 - 665 ft KB Cement 400 sx Circ to Surface DV Tool @ 2,066 KB ~e~ Pelf (2, :>~;;~,-¢~, -- ~4 4 JSPF, 23 gr Charges STAGE 3: X-Link Frac with 108 Mlbs 20/40 7" Production Casing 7", 23 ppf, 0 - 4034 ft KB Cement in 2 Stage Stage 1: 310 sx Class G, 15.8 PPG Stage 2: 268 Sx Class G, 12.5 ppg (Circ to surface) / 4 JSPF, 23 gr Charges STAGE 2: X-Link Frac with 74 Mlbs 20/40 4 JSPF, 23 gr Charges X-Link Fmc with 125 Mlbs 20/40 Existing Perforations (3,184-3,194) - 10 ft 5 JSPF, 43 gr Charges CIBP @ 3,520' KB Existing Perforations (3,275-3,284) - 9 ff 4 JRPF 4.~ nr C, hRm~s Existing Perforations (3,878-83,3834-38,3748-54,3718.34,3582.90) 5 JSPF, 43 gr charges 3x 871845 Wasiila, AK 99687 Tel:907 357 8130 Fax:907 357 83,t0 www. EvergreenGas,com =V EGI; ==Iq RESOURCES tALASKA) CORP. ,: -~:~-'"~,~"~".' C.~ 5~"-;"~~ qe~%.~'C~, ~¢ May 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: 10-403-Test Casing Evergr. een"~oneer U n it 1702~14C~7~ AP1:~09-20016-00 Permit'. 99,-65 NW of Section 14 Twn 17 North Rng 2 West Matanuska Susitna Borough, Alaska Dear Commissioners Palin, Ruederich and Seamount, Evergreen Resources Alaska Corporation submits the following 10-403 to determine the condition of the subject wellbore. In this operation, we will run a cement bond log, set ,/ a cast iron bridge plug to isolate lower perforations and pressure test casing above existing perforations. If the wellbore is capable of holding pressure, then Evergreen may choose to use it as an alternate water disposal well. Thank you for your help. Please contact me if you have any questions. Sincerely, Evergreen ResouJl=es (Alaska) Corp Alaska Projects Manager Attachments RECEIVED MAY 0 9 2OO3 Alaska Oil & Gas Cons. Commission Anchorage Street: 1075 Check Street, Suite 202 Wasilla, AK 99654 Mailing: P.O. Box 871845 Wasilla AK 99677 Tel 907-357-8130 Fax 907-357-8340 www. EvergreenGas,com ORIGINAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT FOR SUNDRY APPROVALS 1. Type of Request Abandon After Casing Change Approved Program Suspend r-~ Operation Shutdown L' Re-enter suspended well Repair Well !~. Plugging ~ Time extension Pull Tubing ~ Variance Lq' Perforate z'. Stimulate '~: Other 2. Name of Operator Evergreen Resources Alaska 3. Address: P.O. Box 871845 Wasilla, AK 99687 4. Location of well at surface: 5. Type of Well Development Exploratory Stratigraphic Service At top of productive interval: NW of Section 14 Twn 17 North Rng 2 West, Seward Meridian 500 FWL and 820 FSL OF Section Same At effective depth: Same Total depth: Same 6. Datum elevation (DF or KB): 281 ft KB (12 ft AGL) 7. Unit or Property Name: Pioneer Unit 8. Well number: 1702-14CC 9. Permit number: 99-65 /' 10. APl Number: 50-009-20016-00 11. Field and Pool: Pioneer 12. Present well condition summary /. Total depth: Measured 4034 feet Plugs (measured) none true vertical feet Effective depth: Measured 4034 feet Junk (measured) none true vertical feet Casing: Length Size Cemented Measured Depth True vertical depth Structural Conductor 55' 13-318" 364' Surface 665' 9-518" 400 sx 15.8 ppg Class G, Circ to Surface 665' Intermediate Production 4034' 7" Below DV: 310 sx, 15.8 ppg Class G, Above DV 2502' 268 sx 12.5 ppg class G circulated to surface. Liner Perforation depth: Measured True vertical 3878-8~,3834-38,3748-54,37t8-24,3582-90,3275-84,3275-84,318__.4.94 3878-83,3834-38,3748-54,3718-24,3582-90,3275-84,3275.84,3184-94 Tubing (size, grade, and measured depth) 3144 ft, 2-718", 6,7 ppf, K-55, 6 round, EUE Packers and SSSV (type and measured depth) none 13. Attachments: 14. Estimated date for commencing operation Sunday M.~y"tl, 2003..~/'' 16. If proposal was verbally approved Name of approver Date Approved 17. I hereby certify, that the f,~regoing is true and correct to the best of my knowledge. Signed Title Alaska Projects Manager Description Summary of Proposal [] .~.J;)etailed Operations Program [] BOP Sketch [] ,d~,,'''''~''''~ 15. Status of well classification as: Oil [] Gas [] Suspended !::;1 Service Date May 8, 2003 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Approval No. ~.~_-~ -. Plug integrity D BOP test,~ Location clearance ~.~ Mechanical in.tegrity test.~ Subsequent form requir~ed 10- Approved by order of the Commission ,/~~ ~ ~ Commissioner Date S"//'~ky~. Form 10'403 Rev 06/15/88 ~ SUBMIT IN TRIPLICA:rE ORIGINAL RESOURCES IALASKA) CORP. A ~:,,,¢,;~, ,'~ ~,~,',;~:,~,'~ ,~r'~,~.'C~'~' ,'%' Program Summary Pioneer Unit 1702-14CC APl: 50-009-20016-00 Permit: 99-65 NW of Section 14 Twn 17 North Rng 2 West The subject well was spud by Ocean Energy on August 28, 1998 and drilling was completed on September 14, 1998.'/The well reached a total depth of 4050 feet, logs were run and 7", 23 ppf casing was run and cemented. On September 19, 1999, the well completion program commenced and consisted of perforating the Tyonek formation in the intervals below. These perforations were broken down with '349 bbls of 2% KCl and balls at 4.5 to 5.5 bpm. The well was swabbed for 3 days and recovered 108 bbls of load with no gas shows. Currently, there are 101 joints (3,144 ft) of 2-7/8" tubing landed in the 3M tubing head with a 2.205 XN Nipple on bottom. Table of Existing Perforations Interval Feet Holes Formation Shotslft 3,878 -3,873 5 25' .. 3,834- 3,838' 4 2.0 3748 - 3754' 6 30 3718 -3,724' 6 30 Tyonek 5 3582 - 3,590 8 40 3,275 - 3284 9 45 3,184- 3,194 10 50 Totals 48 240 This is an investigation procedure to determine the quality of the production casing. In this procedure, Evergreen will pull the tubing and seating nipple, set a bridge plug above the existing perforations, and pressure test the casing to 1,500 psi for 30 /' minutes. If this test is s.,..u.¢'c6~s~l, Evergreen may utilize this well as a water disposal well. A 3,000 psi mafi'~al BOP will be tested and deployed in this system. Evergreen will ut(li-z~ftE~(~wn cement pump, single-double work over rig and water trucks currently residing in Wasilla. As specified in 20 AAC 25.280 (b)(4), fresh water will be used to control the well. A high pressure cementing or fracturing pump will be on location to kill the well if necessary. We do not expect well control issues on this 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 (,500 ft x 0.435 psi/ft) or 1,686 psig. We plan on using 3,000 psi BOPE. Re~lulation Exceptions 20 AAC 25.285: Evergreen requests that our manual BOPEs, as illustrated on the next / two pages be acceptable for the frac and the clean-out operations. 20 AAC 25.287: Evergreen requests that our Fullbore lubricator and spool on top of the Demco Frac Valve is acceptable. Street: 1075 Check Street, Suite 202 Wasilla, AK 99654 Maiing: P.O. Box 871845 Wasllla AK 99677 Tel 907-357-8130 Fax 907-357-8340 www. EvergreenGas.c0m RESOURCES IALASKA} CORP. BOP DETAIL BOP DETAIL FOR WORKOVER OPERATIONS A schematic of Evergreen's BOPE for workover operations is shown in the adjacent figure and detailed in the table below. We will ulJlize this set-up after the fracture treatment to retrieve (via tubing) the bridge plugs and to clean-out sand in the wellbore. Here we propose using 3,000 psi, 7-1/16 inch BOPE manually operated system. The BOP is attached to the 9-5~8" casing head which is also our spool in this operation. , Size Psi No Item Manufacturer (in) Rating. 1 Valve FMC or equivalent 2 3,000 2 Valve FMC or equivalent 2 3,000 3 Valve FMC or equivalent 2 3,000 4 Valve FMC or equivalent 2 3,000 5 Tubinghead & Spool Wellhead Inc 7"x 2-7/8 3,000 6 BOP: Blind Ram Townsend Manual Operated 7-1/16 3,000 7 BOP: Pipe Ram Townsend Manual Operated 7-1/16 3,000 8 Stripping Head High Tech Tools 7-1/16 3,000 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 3,000 psi and the insert rubber, manufactured by Triple M (Odessa, TX), designed for 2-7/8" tubing, is pressure rated to 1,000 psi. Four manually activated FMC block Valves are attached to the spool - two for the kill I, iJ{~"'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 knowledge with wellbores in this field. Street: 1075 Check Street, Suite 202 Wasilla, AK 99654 Mailing: P.O. Box 871845 Was~la AK 99677 Tel 907-357-8130 Fax 907-357-8340 www. EvergreenGas. com =V=I GR==N RESOURCES {ALASKA} CORP. A ~,~'~,~,r'; 9,~ £,,;','~7'~e'~ ,~',';,~.~'c~3, 'nd Blow Out Prevention Equipment for VVireline O 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/R, 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. )erations Pipe Rams Blind Rams To Pump Well control during Wire line operations Tank . Size Psi Manufacture No Item ,, Manufacturer , (i,n) ,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 Manual Operated 7-1/16 3,000 2001 7 BOP: Pipe Ram Townsend Manual Operated 7-1/16 3,000 2001 8 Full bore lubricator Patterson Wireline 5-1/2 3,000 1999(?) Street: 1075 Check Sleet, Suite 202 Wasilla, AK 99654 Maling: P.O. Box 871845 Wasilta AK 99677 Tel 907-357-8130 Fax 907-357-8340 www. EvergreeaGas.com RESOURCES (ALASKA) CORP. PROPOSED PROCEDURE Pioneer Unit 1702-14CC APl: 50-009-20016-00 Permit: 99-65 NW of Section 14 Twn 17 North Rng 2 West Objective: Test casing integrity above existing perforations by pulling tubing, setting wireline retrievable bridge plug, and pressure testing 7" above top perforation. Elevations: Ground: 269 ft Kelly Busin.q: 281 ft (12 ft AGL) Tubulars: Surface: 677' KB, 9-5/8", 36 ppf, cement circ to surface Production: 4034' KB, 23.0 ppf, CF-50, ST&C, 8 round, PBTD @ 3945' Tubing: 3,144 ft KB, 2-7/8", 6.4 ppf, J-55, 8 rd, EUE, new History: Preparation: 1. Subject well was spud in August 1998. The well was completed in September of that same year by drilling out DV tool at 2072, running scraper, perforating several seams in the Tyonek, breaking those same perforations down with 346 bbl 2% KCL at 5.5 bpm using 1.3 sg balls, and then swabbing the well. No gas produced and 108 bbls of load was recovered. No gas was reported.""l'he well was left with 101 joints (3,144 feet of 2-7/8" tubing). AOGCC: Contact AOGCC (907-279-1433), Winton Aubert, 24 hours prior to operations. 2. Tanks: One flowback tank to recover any spilled tubing --~ 3. Water: One water truck on location loaded with 80 bbls of fresh water from Wasilla. Water must have biocide in it. An equivalent 4% KCI solution will be added to all water pumped/injected into well bore. 4. Water Truck: Evergreen water trucks in Wasilla using DJ Excavation personnel. 5. Water Heating & Steam Services: Sub Zero Thawing, Wasilla 907-376- '2 1569. Bernie Shones has a 2.1 MMBTu Fire Tube Boiler with up to 20 steam lines. Will use this equipment to heat water to 80 deg F for frac. 6. Pumping Services: Evergreen Well Service International Frac Fleet 7. Workover Rig: Evergreen Well Service Rig No. 1696 8. Wireline Operations: Patterson Wireline. Scott Allen (907-354-4529). 9. Haul Tubing: None needed Spills: 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 tank will be in place at all times. Duck Ponds to be placed under all vehicles. Tight Hole: No information from this well may be shared with anyone outside of Evergreen Resources. Street: 1075 Check Street, Suite202 Wasilla, AK 99654 Mailing: P.O. Box871845 WasiltaAK 99677 Tel 907-357-8130 Fax 907-357-8340 www. EvergreenGas.com PROPOSED PROCEDURE (CONTINUED) 1702-i4CC Personneh Evergreen Resources Office: 907-357-8130 Fax: 907-357-8340 Engineer: Shane Gagliardi 907-355-8569 Tool Pusher: Jerry Trout 907-354-4529 AK Proj Manager John Tanigawa 907-841-0000 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: Houston Lodge 907-892-6808 Patterson Wireline: Big Lake Motel 907-892-7976 Map to 1702-14CC Well ,, This well is located on Vine Road, 1.7 miles south of the Parks Highway. This well is located immediately east of the 1702-15DA injection facility on the lease road. Casing and Tubing Data Strengths taken to 100% for Tubinc and 100% off_a_sing Size i Weight iD Drift Collapse Burst I Yield "~-~paeiiy ]Capaci (in) i (ppf) (in) (in) (psi) (psiL,' (klbs)_ Bbls/ff Ft/bb ]'ubiE~__L_~zZ_/..8_..__[ 6.4 2.441 2.347 7_,680 7,260i 72 0.005794 172.. _ ( Casing 7 i 23 6.366 6.151 3,270 4,360I 284 0.03936I 25.40: Annulus __~_b_°.Y__e).l . - ......... i z z - I 0.03133/ 31.91, =V=I GR==N RESOURCES IALASKA! CORP. .~ ~,~::.,~ .?,~ ~, ,~, ~,~.,¢.~,~.~ .~,,-~ ~...;.,.~.,..~- PROPOSED PROCEDURE (CONTINUED) PIONEER 1702-14CC 1. MIRU Evergreen Well Service rig no 6916 and EWS cement pump and water tuck with 80 bbls of city water with biocide and clay stabilizer. Install and Test BOPE to 3,000 psig. Well records indicate that the casing/tubing has 200 psi in 1999 with very little flow of water. Pull 101 Joints of tubing and lay down. MIRU Patterson Wireline. All operations to be conducted under lubricator. Run Cement Bond Log from PBTD 3945 ft KB to surface under 500 psi pressure, if possible. Set 7" Cast Iron Bridge Plug (ClBP) via wireline at 3,520 ft KB. Using wireline bailer, place 2 sx cement on top of CIBP. RDMO Patterson Wireline. RIH w/7" ASX packer on 2-7/8" tubing. Set at 3,450 ft KB. ~'~' Pressure test ClBP to 3,000 psi for 10 minutes. If test fails, contact engineering. Unseat Packer and pull up to +/- 3,155 ft KB. Set Packer Pressure test annulus with 2,500 psi for 10 minutes. If test fails do the following: a. Move above DV tool at 2,072 ft KB and re test to 2,500 psi. b. If this test fails, then pull up every 500 feet and locate the hole. 14. Clean Location. Leave tubing on location. 15. RDMO . . . 7. 8. 9. 10. 11. 12. 13. Slreet: 1075 Check Street, Suite 202 Wasilla, AK 99654 Maling: P.O. Box 871845 Wasilla AK 99677 Tel 907-357-8130 Fax 907-357-8340 www. EvergreenGas.c0m 170244CC APl Sec 14 17N Rng 2w Matanuska,Susi(na State Alaska Pioaeer Unit Country USA 289/281 Depth [Length OD ID i Thread ST&C LT&C 8 Rd Description .3878-3883 perf 5 spf HCS i3834-3838 pe_~ 5 spf HCS 61N/A .,3748-3754 perf 5 spf HCS 6iN/A !3718~3724 peal 5 spf HCS 81N/A 3582-3590.p_ed 5 spf HCS 9iN/A 3275-_~_.2.84 perf 5 spf HCS 10N/A xl/A ~3184-3194 perf 5 spf HCS 31441 I 2.875 2.3; Md 715E stag.e....?llar (drilled out) 3143 2.441 2-7/8 J-55 EUE Tbg PBTD 3945 Created by STG 5/8/03 Modified February 7, 2000 Mr. Bob Crandell State of Alaska, Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: Pioneer Unit 1702 ,4 14 CC Dear Mr. Cradell; AP! # 009-20016-00 Permit if 199-065 Enclosed for the subject well is the requested completion summary for the subject well. If you have any questions or need additional information on this matter, please call Doug Walton at (303) 308-8867. Sincerely, Scott M. Webb Regulatory Coordinator FEB 7 2000 Alaska Oil ~.G~ Cons. Commi,~ion Ocean Energy, Inc. Amoco Building 1670 Broadway, Suite 2800 Denver, Colorado 80202 (303) 308-8500 Fax: (303) 308-8510 December 28, 1999 State of Alaska, Oil and Gas Conservation Commission 3001 Porcup/ne Drive Anchorage, Alaska 99501 RE: Pioneer Unit 1702 # 14 CC Dear Madam or Sir; API# 009-20016-00 Permit # 199-065 Enclosed for the subject well completion report are the following items: Form 10-407 (original and requ/red copies) Inclination report Logs ran on this ~vell If you have any questions or need additional information, I can be reached at (303) 308-8863. Sincerely, Scott M. Webb Regulatoly Coordinator RECEIVED Ai~ 'ka 0il & 6as Cons. O0mrnissi0B Amoco Building 1670 Broadway, Suite 2800 Denver, Colorado 80202 (303) 308-8500 Fax: (303) 308-8510 ...... STATE OF ALASKA ALASKA OIL ,- ND GAS CONSERVATION C. MMISSION WELL 6OIVIPLETION OR RECOMPLETION REPORT AND LOG I1. Status of Well Preliminary Report (Well Shut-in) Classification of Service Well OiL: GAS: XX SUSPENDED: ABANDONED: SERVICE: 2. Name of Operator 7. Permit Number Ocean Energy Resources, Inc. 199-065 3. Address 8. APl Number 1670 Broadway, Suite 2700, Denver, Colorado 80202-4826 50- 009-20016 4. Location of well at surface i'~:'.,:~,~,-i;~-' ~'i'f-~i~-i ,:~ ............ 9. Unit or Lease Name 500' FWL 820' FSL Sec. 14-T17N-R2W i ' ": ~':'.,_i' "~ ~ Pioneer Unit 1702 ,~ 1142' FWL & 517' FSL Sec. 14-T17N-R2W ~-~~-~-'--~:~ ...... :.:. :. 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Pioneer Unit / Tyonek KB: 292'I ADL-374117 12. Date Spudded 8/26/99 13' Date T'D' Reached I 14' Date C°mp" Susp' °r Aband' I 15' Water Depth' if °fish°re f 16' N°' °f C°mp'eti°nsI 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) ] 19. Directional Su~ey J 20. Depth where SSSV set 21. Thickness of Permafrost MD: 40,50' TVD 3980' MD 3928' I Yes: XX No: I NA feet MD NA 22. Type Electric or Other Logs Run Neutron, DIL, CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP - Bo'FrOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 13-3~8" 68# J-55 Surf. 35' 17-1/2" 30 sx class "G" None 9-5~8" 36:~ K-55 Surf. 677' 12-1/4" 400 sx class "G" None , . 7" 23# CF-50 Surf. 4034' 8-3/4" 856 sx class "G" None 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) .. SIZE DEPTH SET (MD) PACKER SET (MD,) 3184'- 3883' 5 SPF .45" Hole 2-7/8" 3144' 3135' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Date First Production I Method of Operation (Flowing, gas lift, etc.) 10108199I Swabbed, well currently shut-in. A~8.$~'3. 0il & Gas Cons. Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATEFABI~tIL0r t~]-IOKE SIZE I GAS-OIL RATIO 10/8/1999 24 TEST PERIOD => 0 0 0 I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. SlTP 380 PSI 24-HOUR RATE => 0 0 0 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Glacial Deposits Surf. Tyonek 480' Tyonek "B" Coal 1056' Tyonek "C" Coal 2040' Tyonek BLT Sand 3440' 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed.,/"'~'~'_? ~ L-" .--~/'~.~'""'Title Regulato ry Coordinator Da te 12./27/99 INSTRUCTIONS , · :. , General: lhis form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other space on this form and in any attachments. _ Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the productin intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Operations Activity Summary Well ID: Pioneer 170214C(:; Well Name: Pioneer Unit #.1702-14CC Ocean Energy Page 1 Rpt. Ops N~'~- NO. Dat~Tim~ Fr~nl To Hm C6de Pf~uct I 2?-Aug-g9 ~:~ 7:~ 7 ~D 27~u~-~g 7:00 20:00 13 ~0~ 27-Aug-~9 23:00 o:oo 1 3 2g~jg-9~ 0:00 1:30 I,¢ D~ILL ~-Aug-9~ 1:3o ~:3c 1 2~-~9.~9 ~'-~ 10:00 I 2~A~6.99 10:~0 12;00 2 2g-Au~-9~ 12:~0 !4;30 ~9~¢g-9~ I~;50 1~;00 1.5 29-~g-99 18:0~ 1~:3~ 0,5 SURV Zg-A~g-99 16;32 !~:0~ 1,E TRPO 29.Au799 22:~ 0:00 2 C~RC 6:52 A~tvity D~--rlption rig clown,, prepere for move .move fig from 1702-14DA I:~ 1702.14C.0, prepar~ to drill 3~7 - 369 42 ft, 25 fph cir & wlfeline ~;~l've¥ 329 1/2 dog :3P~ - 680 311 ft, 47.8 cir & condition .~rier tQ sl~ort paoh wJo ~roble~s, re;nor ~bbl~ 5 -~ 5 k, ~n=lug 2 J~ from w~jne su~ey~ ~9, 1 1/[ ~ah to run csg, ~d 8" dC run !5 its ~ 5/8 3~ K-S~ STC, had ~0 wor~ a couple ~f times when ~r ~st j[ to b~, no a~amnt fill, Lower yd ~3 6 , En~ of Well Summary Report Well ID: Pioneer 170214CC Ocean Energy Well Name: Pioneer Unit #1702-14CC Operator: AFE Nos: Spud Date: Section: Location: Ocean Energy, Inc. DND971C; DND971D Field: Pioneer Unit 14 Township: 17N Range: 500' FWL, 820' FSL 2W Reports for 06:00 on date shown 27-Aug-99 Mud Data: Surveys: Days S.S.: Current Depth: 50 Hole Drilled: 50 Ave ROP: Present Cps: drlg ahead at 85 ft Operations Summary: rig down, prepare for move (7 hfs) move rig from 1702-14DAto 1702-14CC, (13 hfs) prepare to drill (1 hrs) Comments: rig move went pretty good, rig was spotted by 1600 hfs, and rest rental equipment by 2100 hrs. Have some misc cleaning up to do on the 1702-15DA yet. Mud loggers equiment not all up and running yet None None 0 Daily Costs: $107,375 Well Costs: $107,375 28-Aug-99 Current Depth: 327 Hole Drilled: 277 Ave ROP: Present Cps: drlg ahead @ 475 ft, have a plugged nozzle so pump rate is now 310 gpm w/1350 psi. Do have float installed in BS Operations Summary: 29-Aug-99 Comments: had a lot of trouble at 135 ft to 189. Acted like boulders but hole would Mud Data: Surveys: Days S.S.: Current Depth: 50 Hole Drilled: Operations Summary: 327 - 369 42 ft, 28 fph (1.5 hfs) cir & wireline survey 329 1/2 deg (1 hfs) 369 - 680 311 ft, 47.8 fph (6.5 hfs) cir & condition prior to short trip (1 hfs) pooh w/o problems, minor bobbles 5 -1 5 k, unplug 2 jets from bit (2 hrs) tih, (2.5 hrs) pack off ccc. Could pu the boulders with bit and get them on top of bit. Found had to use very slow rpm and wt to break them up and get through this spot. Hole would take a drink and then give most of it back. None None 1 Daily Costs: $46,927 Well Costs: $154,302 Ave ROP: Page 1 Well Summary Report Well ID: Pioneer 170214CC Ocean Energy Well Name: Pioneer Unit #1702-14CC 30-Aug-99 31 -Aug-99 cir & condition to run csg (1.5 hrs) wirline survey@ 649, 1 1/2 deg (0.5 hrs) pooh to run csg, Id 8" dc (1.5 hfs) run 15 jts 9 5/8 36# K-55 STC, had to work a couple of times when entered tyonek. But nothing major, (4 hrs) cir last jt to bttm, no apparent fill. Lower yd to 8 (2 hrs) Mud Data: MW: 9.2 Viscosity: 170 Filtrate: 8.8 HTHP Filtrate: 0 Surveys: None Days S.S.: 2 Daily Costs: $31,790 Well Costs: $186,092 Current Depth: 680 Hole Drilled: Ave ROP: Present Ops: rih, w bit #2 8.75 Operations Summary: cir & condtion mud, reduce yld to 8, vis to 41, st to 8.8 (0.5 hrs) safety meeting, cmting (0.5 hrs) cmt surface pipe, 10 bbls, mcs-a spacer, 84 bbls 15.8 ppg cmt, dispalce w/46 bbls water, no cmt to surface (0.5 hfs) woc, perfor 1" top job @ 120 ft, cir w/15 bbls fin prior, fllushed out a trace of cmt, pumped 18 bbls 15.8 cmt w/2% cacl, cmt to surface @ 10 bbls, (6 hfs) cut off conductor, install 9 5/8 SOW x 11" 3M well head, test to 1000 psi, (5.5 hfs) nu hope, (8 hrs) test bope, 250 low, 3000 high. (3 hfs) Mud Data: MW: 8.7 Viscosity: 37 Filtrate: 30 HTHP Filtrate: 0 Surveys: None Days S.S.: 3 Daily Costs: $37,820 Well Costs: $223,912 Current Depth: 694 Hole Drilled: 14 Ave ROP: 1.9 Present Ops: cir, prior to pooh to pu storm packer, prior to rig change out Operations Summary: test bope, 250 Iow, 2500 high, had 4 leaks to fix but otherwise OK. Witnessed by John Spauling,AOGCC (3.5 hfs) pu NB #2, 5 DC, tih to 525 (4 hrs) test csg to 850 psi for 30 min (0.5 hrs) Id excess dp (1 hrs) wash 525 to 575, install rot head, bit plugged, try to unplug bit w/o success (2 hfs) pooh, Id 5 dc, unplug bit, all 8 nozzles plugged w/rocks and even a lego toy?? (2.5 hrs) change jets from 10 to 12's, tih to 575 (1.5 hrs) drill cmt, float collar, and shoe do 5 min 850 pressure test on float collar and shoe jr. (5 hrs) 680-694 14 ft, 60 fph (0.5 hrs) cid & perform Fit to 11.5 EMW (0.5 hrs) clean mud tanks, make new phpa mud. 1.5 ppb phpa (3 hfs) Page 2 Well Summary Report Well ID: Pioneer 170214CC Ocean Energy Well Name: Pioneer Unit #1702-14CC 01 -Sep-99 02-Sep-99 03-Sep-99 Comments: got phpa mud made and started to drill @ 0200 9-1-99. Drlg very good but sample quality poor, losing mud over shakers, will replace screens (rig does not have coarser screens at this time) as Soon as can get them. Shut down at 0430 to cir to clean up hole for rig change out. Mud Data: MW: 8.4 Viscosity: 56 Filtrate: 18 HTHP Filtrate: 0 Surveys: None Days S.S.: 4 Daily Costs: $54,820 Well Costs: $278,732 Current Depth: 882 Hole Drilled: 188 Ave ROP: 75.2 Present Cps: ru CHP rig 23 Operations Summary: make & change out mud to phpa, dispalce hole (1.5 hrs) 694 - 819 125 ft, 61 fph (1.5 hfs) change out shaker screens on drying shaker, losing mud over shakers, rig does not have any coarser screens at present time (0.5 hfs) 819-88266ft 66fph (lhrs) cir hole clean prior to pooh to pu storm packer (0.5 hrs) Id 8 jts dp, pu 9 5/8 Halco storm packer and set at 15 ft (3 hrs) rd mo CHP rig #19 (4 hrs) mi RU CHP rig #23 (12 hrs) Comments: CONTINUING W/RIG SWAP will take longer than expected, but going OK Mud Data: MW: 8.4 Viscosity: 44 Filtrate: 18 HTHP Filtrate: 0 Surveys: None Days S.S.: 5 Daily Costs: $20,147 Well Costs: $298,879 Current Depth: 882 Hole Drilled: Ave ROP: Present Cps: ru rig 23, preparing to drill mouse hole at present. Operations Summary: change out rig, ru CHP 23 (24 hrs) Comments: change out taking much longer than expected, AOGCC, John Spaulding here to witness pressure test on BOP Mud Data: MW: 8.4 Viscosity: 44 Filtrate: 18.4 HTHP Filtrate: 0 Surveys: None Days,S.S.: 6 Daily Costs: $0 Well Costs: $298,879 Current Depth: 880 Hole Drilled: -2 Ave ROP: Present Cps: rih w/8 jts., no problems, install dr bushing for rot head, grinding drive bushing to fit kelly at 0430 hrs. As soon as get to fit will start to drl. Have a minus 2 ft drlg due to higher KB on this rig 23 as compared to rig 19, 11.75 vs 10.33 Operations Summary: test blinds rams, choke manifold line to 2500 psi, witnessed by AOGCC, John Spaulding (2.5 hrs) Page 3 Well Summary Report Well ID: Pioneer 170214CC Ocean Energy Well Name: Pioneer Unit #1702-14CC 04-Sep-99 05-Sep-99 drlg rathole, w/mtr, start w. 11.75 bit, drld 15 ft & no forward progress, pu 8.75 bit and drl pilot hole to 50 ft., then drlg out pilot hole. Had to do this a number of times to get the rathole in. Still lack 3 ft but useable.. Ld mtr (15.5 hrs) retireve & Id storm pkr. Lost no volume or gain no volume in hole. (2 hrs) clean mud tanks, pu kelly, upper & lower kelly cock, tighten same (4 hrs) Comments: dewatering while waiting on rig Mud Data: MW: 8.45 Viscosity: 38 Filtrate: 13.6 HTHP Filtrate: 0 Surveys: None Days S.S.: 7 Daily Costs: $31,008 Well Costs: $329,887 Current Depth: 1676 Hole Drilled: 796 Ave ROP: 51.4 Present Cps: drlg ahead @ 1845. Looking for core pt Operations Summary: test upper & lower kelly cock 300/2500 (2 hrs) cir bu, pu 8 its dp, rih to bttm, install rot head (2 hrs) cir while grinding down rot head drive bushing to fit kelly. (2 hrs) 880 - 1138 258 ft, 64.5 fph (4 hrs) wireline survey @ 1107 1 1/2 deg (1 hrs) 1138 - 1347 209 ft, 52.25 fph (4 hrs) clean shaker screens (0.5 hrs) 1347 - 1545, 198 ft, 39.6 fph (5 hrs) lube & service rig (0.5 hfs) 1545 - 1640 95 ft, 63.33 fph (1.5 hrs) wireline survey @ 1609, 1 1/2 deg (0.5 hrs) 1640 - 1676, 36 ft, 36 fph (1 hrs) Comments: all going pretty smoothly since started to drill again. Rig runs much better, Mud Data: MW: 8.75 Viscosity: 39 Filtrate: 9.8 HTHP Filtrate: 0 Surveys: None Days S.S.: 8 Daily Costs: $22,197 Well Costs: $352,084 Current Depth: 1960 Hole Drilled: 284 Ave ROP: 40.6 Present Cps: reaming 6 1/4 core hole, 2066 is 0445 depth drlg 60-90 fph Operations Summary: 1676 - 1930 254 ft, 36.28 fph (7 hrs) cir & run wireline survey at 1924, 2 deg (1 hrs) cir & cond, bbg drop to 15 units, shakers very clean (0.5 hrs) pooh f/core #1, no problems, SLM .87 short, no correction (2.5 hrs) pu 5.75 core bbl w/6 1/4 x 3 1/2 core bit ARC-325 (0.5 hrs) tih w/core #1 (1.5 hrs) wash 40 ft to bttm, cbu, drop ball (1 hrs) cut core #1 1930 - 1960 (3 hfs) pooh w/core #1 Id same, 30 ft recovered, 100% recovery (3 hfs) tih w/bit#2 rr, pu 60 -90 pendulem, 1 more dc, tih to 1910 (4 hrs) Page 4 Well Summary Report Well ID: Pioneer 170214CC Ocean Energy Well Name: Pioneer Unit #1702-14CC 06-Sep-99 07-Sep-99 Comments: 100% recovery in core #1, NO COAL, geology says drill ahead to TD, will try again next well. Core hole reamed fairly easy one nozzle plugged on the bit Mud Data: MW: 8.75 Viscosity: 43 Filtrate: 10.4 HTHP Filtrate: 0 Surveys: None Days S.S.: 9 Daily Costs: $20,527 Well Costs: $372,611 Ave ROP: 37.6 Current Depth: 2467 Hole Drilled: 507 Present Cps: drlg ahead at 2650 Operations Summary: install rot head rubber (0.5 hfs) open core hole f/6.25 to 8.75 1930-1960 (2.5 hfs) 1960- 2141 181 ft, 27.84 fph, bit balled up last 30 ft tried w/o successs to unball (6.5 hrs) lube & service rig (0.5 hfs) pooh, bit balled up (3 hfs) install wear bushing (1 hfs) tih w/bit #2 rr, wash 70 ft to bttm, no fill (3 hrs) 2141 - 2467 326 ft, 46.57 fph (7 hfs) Comments: bit balled just after conn at 2110 work with it to 2141, pooh, clean bit, rib, added med nut plug for 3 hrs after back on bttm to help prevent bailing and added extra phpa for same reason, geology is upset over this. Says is hard to see samples and worry LCM will get into coals. WL is 10 or less and have no mud losses. Can it get in the coals Looks as if running 150 ft high to 1702-15DA well PHPA 1 Ib/bbl Viscosity: 47 Filtrate: 8.8 HTHP Filtrate: 0 Well Costs: $417,765 Ave ROP: 41.0 Mud Data: MW: 8.8 Surveys: None Days S.S.: 10 Daily Costs: $45,154 Current Depth: 3267 Hole Drilled: 800 Present Cps: depth at core pt is 3277, pu core bbl at 0430, Operations Summary: 2467-2539 72 ft, 36 fph (2 hrs) wirleine survey 2509 2 deg (0.5 hrs) 2539 - 2822 283 ft, 43.53 fph (6.5 hrs) lube & service rig, replace nipple on choke line (1 hrs) 2822 - 3041 219 ft, 36.5 fph (6 hfs) woreline survey at 3001, misrun (0.5 hrs) 3041 - 3261 220 ft, 48.88 fph (4.5 hrs) cir samples as per geology (1 hfs) wireline survey @ 3229 3 1/2 deg (0.5 hrs) cir, woo from geologyn (0.5 hrs) Page 5 Well Summary Report Well ID: Pioneer 170214CC Ocean Energy Well Name: Pioneer Unit #1702-14CC 08-Sep-99 09-Sep-99 3261 - 3267 6 ft (0.5 hrs) cir samples for geology, (0.5 hrs) Comments: at 2100 hrs, 3261, cir samples, cut 3 more 5 ft intervals & cir samples for each, looking for core pt. Core pt found at 3277 phpa 1 ppb Mud Data: MW: 8.8 Viscosity: 46 Filtrate: 9.6 HTHP Filtrate: 0 Surveys: None Days S.S.: 11 Daily Costs: $26,085 Well Costs: $443,850 Mud Data: Surveys: Days S.S.: Current Depth: 3299 Hole Drilled: 32 Ave ROP: 32.0 Present Cps: top of core hole reamed hard, started drilling at 0430 9-9-99 Operations Summary: 3267 - 3272 5 ft (0.5 hrs) cir samples as per geology (0.5 hrs) 3272 - 3277 5 ft cir samples as per geolgoy (0.5 hfs) pooh for core #2 (2.5 hrs) pu 5 3/4 core bbl, 6 1/4 x 3 1/2 bit, (4.5 hfs) space out, drop ball, cbu (1 hrs) cut core #2 3277 - 3299, 22 ft, 2.75 fph, geologists said "uncle" (8 hrs) pooh w/core #2 Id & recover same recover 22 ft 100%, recover 7 ft of coal in core (3.5 hrs) pu bit #2 rr, tih (3 hfs) Comments: spoke w/geologists and was prepared to pooh after drilling 10 ft coal section for rapaid recovery of the coal core. (geology on loc gave orders to continue additional footage so as to see possible gas sand in lower end of core.) recovered 7 ft of coal in core geologists says 4100 ft is TD (will drill to pipe depth to land csg on floor) driller misunderstood and left out stabilizers, so bha is slick. Phpa 1 ppb MW: 8.9 Viscosity: 39 Filtrate: 9.2 HTHP Filtrate: 0 None 12 Daily Costs: $0 Well Costs: $443,850 Current Depth: 3516 Hole Drilled: 217 Ave ROP: 31.0 Present Cps: running survey's, lost single shot in hole and then fishing tool also. Line parted Operations Summary: ream core hole 3277 - 3299. Top part reamed hard but after hit coal went well. May have had partial bailing of bit and got it wiped off and then was able to get a good bite. (4.5 hfs) 3299 - 3406 107 ft, 35.6 fph (3 hrs) lube & service rig (0.5 hrs) suvey @ 3396, #1 misrun, #2 7 deg plus (edge of disk) (1 hfs) Page 6 Well Summary Report Well ID: Pioneer 170214CC Ocean Energy Well Name: Pioneer Unit #1702-14CC 10-Sep-99 Mud Data: Surveys: Days S.S.: 3406-3437 31 ft, 62 fph (0.5 hrs) survey @ 3396, 7 deg plus (edge of disk) (0.5 hrs) pooh w/o problems, clean bit and one plugged jet (3 hrs) tih w/Bit #2 rr, 8 -12/s, pu stab at 60 & 90 ft. To 3250 (3 hrs) ream 3250 - 3437 w/o problems, took just a couple pts to ream core hole but otherwise no problem (2 hrs) 3437 - 3512 75 ft, 25 fph, wob 10-15k, rpm 140 (3 hrs) survey @ 3506 misrun w/single shot (0.5 hrs) repair #1 pump motor, glow plug blew out. While down took 3 surveys w/single shot, 1 misrun, 1 10 deg tool (off scale), 1 20 deg tool (off scale) (1.5 hrs) 3512-3516 4 ft, 8 fph (0.5 hrs) single shot @ 3506, w/90 deg tool. 25 deg (0.5 hrs) Comments: when made first survey today that was misrun, 2 disks fell out of the tool. These were up around the pendelum. One was from this survey as the disk was missing from the holder and the other may have been there for quite some time. It may be that the 2nd disk was along side the pendelum and so we could not get true readings from the survey tool. Phpa .75 ppb MW: 8.9 Viscosity: 42 Filtrate: 9.2 HTHP Filtrate: 0 None 13 Daily Costs: $28,318 Well Costs: $472,168 Current Depth: 3516 Hole Drilled: Ave ROP: Present Ops:@ 0430 9-11-99, drlg at 3570, ave 14 fph w/25k wob 63 rpm, all goin OK, survey wire just arrived, will install ASAP Operations Summary: single shot survey at 3502, 25 deg (0.5 hfs) pooh to 3300 ft, 3 stds (0.5 hrs) single shot survey, wireline parted left in hole, pu fishing tool and rih, on second trip wireline parted. (2 hrs) pooh to retrieve single shot (3 hfs) ru Baker Atlas< run dipmeter to check inclination and azmith. 24 deg at 3506 to 1 at 678. Ave 1 deg build per 117 ft (7 hfs) test bope 300 Iow, 2500 high. Informed Blair Wondzell, AOGCC but no inspector arrived loc. (5 hrs) pu nb #4, F14T w/3 14's, 30-60 pen w/8 1/2 and 8 3/4 respectivily, pu 6 additional dc, no problems, install rot head (5.5 hrs) ream, 3450 - 3500, precautionary only (0.5 hrs) Comments: papa .75 ppb Mud Data: MW: 8.8 Viscosity: 42 Filtrate: 9.66 HTHP Filtrate: 0 Surveys: None Days S.S.: 14 Daily Costs: $35,475 Well Costs: $507,643 Page 7 Well Summary Report Well ID: Pioneer 170214CC Ocean Energy Well Name: Pioneer Unit #1702-14CC 11 -Se p-99 12-Sep-99 Current Depth: 3926 Hole Drilled: 410 Ave ROP: 21.0 Present Cps: drlg at 4000 ft at 0400 9-12-99 nest srvey at TD Operations Summary: ream 3500- 3516, no problems no fill. (0.5 hrs) 3516 - 3598 82 ft 14.9 fph, wob 25, rpm 70 (5.5 hfs) lube & service rig, respool .092 survey wire (1.5 hfs) single shot wireline survey at 3587, 22 deg (0.5 hfs) 3598 - 3693 95 ft, 19 fph wob 30-35, rpm 90 (5 hfs) single shot wirline survey at 3682m 20 deg (0.5 hfs) 3693 - 3789 96 ft, 32 fph wob 37-38, rpm 90 (3 hfs) single shot wireline survey at 3787, 18 deg (0.5 hrs) 3789 - 3884 95 ft, 23.75 fph wob 37-38, rpm 85-90 (4 hrs) single shot wireline survey at 3875, misrun, no picture (0.5 hrs) 3884 - 3916 32 ft, 21.33 fph (1.5 hfs) single shot wireline survey at 3905, no picture (0.5 hfs) 3916 - 3926 10 ft, 20 fph (0.5 hfs) Comments: one centrifuge taken out of solids van for repairs.main bearings went out. Phpa .7 ppb drlg ahead to 4050, geologists say base of last large coal section at 3900. Drl to fit pipe at 4034 with extra 15 ft drld for rathole hole dropping angle at 2 deg/100 very consistenly last survey at 3936 was 14 deg, switched to 20 deg clock MW: 8.9 Viscosity: 46 Filtrate: 8.4 HTHP Filtrate: 0 None 15 Daily Costs: $18,568 Well Costs: $526,211 Mud Data: Surveys: Days S.S.: Current Depth: 4050 Hole Drilled: 124 Ave ROP: Present Cps: logging, SWC run #2 Operations Summary: 3926 - 3947 21 ft, 21 fph wob 38, rpm 990 (1 hrs) single shot wireline survey at 3936, 14 deg used 20 deg clock (0.5 hrs) 3947 - 4050 TD 103 ft 20.6 fph (5 hrs) single shot wireline survey at 4032 13 1/4 deg (0.5 hrs) cir & cond mud (1 hrs) pooh 25 stds, 20 k op max on first 4 stds (1.5 hfs) tih w/o problems, 10-15 k max so (1 hrs) cir, 58 units trip gas (1 hrs) pooh f/logs, SLM 4.25 long, no correction (4 hrs) safety meeting w/Baker Atlas, logging (0.5 hrs) 20.7 Page 8 Well Summary Report Well ID: Pioneer 170214CC Ocean Energy Well Name: Pioneer Unit #1702-14CC 13-Sep-99 13-Sep-99 14-Sep-99 log w/Baker Atlas, run #1 DAL-HDIL-GR 4042-0 (3 hrs) Run #2 ZDL-CNL-GR-CAL 4042-0 (4 hrs) Run#3 sidewall cores, coal samples (1 hrs) Mud Data: MW: 8.9 Viscosity: 41 Filtrate: 9.8 Surveys: None Days S.S.: 16 Daily Costs: $18,668 Current Depth: 4050 Hole Drilled: Operations Summary: HTHP Filtrate: 0 Well Costs: $544,879 Ave ROP: run SWC #1 coal 6 intrvals, 3284-3276 5 shots, 2742-2748 4 cores, 2546-2570 4 cores, 2070-2080 4 ocres, 1805-1814 4 cores, 1464-1468 4 cores (2.5 hrs) run SWC #2 9 sand intervals, 3762-3826 3 cores, 3600-3628 3 cores, 3456-3556 3 cores, 3314-3346 3 cores,3210-3265 3 cores, 2690-2720 3 cores, 2104-2144 3 cores, 1240-1274 2 cores, 1110-1150 2 cores (3 hrs) Mud Data: None Surveys: None Days S.S.: 17 Daily Costs: $22,380 Well Costs: $567,259 Current Depth: 4050 Hole Drilled: Ave ROP: Present Ops: cir, & cmt first stage,cmt first stage @ 0300 hfs, finish at 0400 hrs 9-14- 99, open DV and cir for 2nd stage at RT Operations Summary: retrieve wear bushing (0.5 hrs) tih, pu 8.75 stab at 60 ft, (2.5 hfs) ream 28 ft to bttm, cir & cond mud prior to Id dp, mix & pump slug (2.5 hfs) Id dp & dc, break kelly (5 hrs) install 7" csg rams (1 hfs) run 96 jts, 7" 23# CF-50 LTC csg, no problems 15k max slack off (7 hrs) Comments: csg went to bttm w/o problems 15 k so max. Broke cir w/oproblems Mud Data: None Surveys: None Days S.S.: Daily Costs: $59,869 Well Costs: $627,128 Current Depth: 4050 Hole Drilled: Ave ROP: Operations Summary: ru BJ and cir head, cir at 8 bpm 500 psi. (2.5 hfs) safety meeting, cmting (0.5 hfs) cmt 1st stage, 20 bbls 11.5 spaceer, 314 sx "G" (64 bbls), follow w/81 bbls water and 73 bbls mud (1.5 hfs) Mud Data: MW: 0 Viscosity: 0 Filtrate: 0 HTHP Filtrate: 0 Surveys: None Days S.S.: Daily Costs: $0 Well Costs: $627,128 Printed: 12:59 25-Apr-O0 Page 9 COMPLETION SUMMARY PIONEER UNIT 1702-14CC 09/18/99 09/19/99 09/20/99 09/21/00 09/22/99 09/23/99 09/24/99 09/25/99 09/26/99 09/27/99 MIRU CH&P RIG 19. NU AND TEST BOPE AND MANIFOLD. FORWARD TEST RESULTS TO AOGCC. PU 6 ¼" BIT AND 2 DC'S. RIH W/2 7/8" EUE TBG. DRILL ON CEMENT FILL AT 1822'. DRILL OUT DV TOOL AT 2072'. WASH DOWN TO PDTD AT 3945'. CIRCL~ATE HOLE CLEAN. POOH W. TBG. RU ATLAS WIRELINE. RUN CBL FROM PBTD ~ 3945' TO 3500' W/0 PSI. REPEAT CBL FROM PBTD TO SURFACE W/750 PSI. FORWARD CBL TO AOGCC. SLIGHT LEAK DEVELOPED ON 4" NIPPLE ON WELLHEAD WHILE LOGGING. UNABLE TO REMOVE NIPPLE FROM WELLHEAD. ND BOP. REPLACE WELLHEAD. NUBOPE AND MANIFOLD. RETEST ALL SURFACE EQUIPMENT TO 2000 PSI. PU BIT AND CASING SCRAPER AND TIH TO PBTD. CRICULATE HOLE W/2% KCL WATER. SWAB FL TO 650' SWAB FL TO 1300'. SD FOR RIG REPAIR. SWAB FL TO 2100'. POOH W/TBG. RU ATLAS WIRELINE. PERFORATE W/4 ½" HSC 5 JSPF 43 GRAM CHARGES .45" PERFS: 3878-83', 3834-38', 3748-54', 3718-24', 3582-90', 3275-84' & 3184-94' 48' 240 TOTAL SHOTS. NO MEASURABLE PRESSURES AFTER PERFORATING. SICP 0 PSI. TIH W/BAKER RETRIEVAMATIC PACKER AND 2 7/8 TBG. SET PACKER AT 3142'. RU TO SWAB ALL ZONES TOGETHER. IFL 1374'. MADE 4 RUNS AND LOST SINKER BAR AND MANDREL. RELEASE PACKER AND POOH W/TBG. SITP/CP 0/0 PSI. FINISH POOH W/TBG TO RETRIEVE SWAB TOOLS. RERUN PACKER AND TBG. SET PACKER AT 3142'. RU SWAB. SWAB TO XN NIPPLE AT 3142'. RECOVERED 9 BBL FLUID. SITP 0 PSI RU SWAB. IFL 3070'. NO FLUID RECOVERY RECEIVED SITP 0 PSI RU SWAB IFL 3100'. NO FLUID RECOVERY. RU DOWELL TO BD ALL PERFS W/250 BBL 2% KCL WATER ~ast~a Oil & 09/28/99 09/29/00 10/29/00 500 BALL SEALERS. FLUSH W/50 BBL 2% KCL WATER. FINAL RATE 5.5 BPM 2885 PSI. ISIP 2460 PSI 15 MIN 2140 PSI. SWAB BACK BD FLUID. RECOVERED 36 BBL OF 300 BBL LOAD. SITP 1150 PSI. SWAB BACK BD FLUD. RECOVERED 39 BBL FOR DAY. 75 BBL OF 300 BBL TOTAL LOAD RECOVERED. SITP 0 PSI RU SWAB IFL 1200'. SWAB TO XN NIPPLE AND MADE 1 RUN/HR FOR 3 HRS. FINAL RATE 1.5 BPH. 15 BBL FLUD RECOVERED. 90 BBL OF 300 TOTAL LOAD RECOVERED. RELEASE PACKER AND POOH. LD PACKER. TIH W/2.205 XN NIPPLE AND 101 JTS 2 7/8" 6.5# J55 EUE TBG. LAND TBG AT 3144'. ND BOPE NU WELLHEAD. RDMO CH&P RIG 19. SECURE WELLHEAD W/CHAINS AND LOCKS. INSTALL WELLHEAD SHELTER. SI WAIT ON FRAC EQUIPMENT. RECEIVED -D~PTH 6£B. 00 6-'78, O0 728. O0 ?TB. O0 8,38. OD B?8. O0 92B. O0 078. O0 1028, OD 1078. O0 1128.00 1178. O0 1228,00 1278. O0 1328.00 1378, OD 1428, O0 1478.00 15~8,00 1578. O0 1828. O0 1878,00 1728.00 1778. O0 1838 ,OD 3878. O0 1928.00 1078 .OD 2028. O0 2078,00 2128.00 2178.00 2228, O0 2278.00 2328. O0 2378, O0 2428. O0 2478. O0 2528,00 2578. O0 2628. O0 2678. O0 2728. O0 2778, O0 2828. O0 2878. O0 2928 O0 2078 O0 3028 O0 3078 O0 3128 O0 3178 O0 3228. O0 3278. O0 3328, O0 33?8. O0 3428, O0 3478,00 3508. O0 .0 .0 1,0 143,9 1,2 99,8 1.3 99.0 1,4 99,2 1,5 98,8 1.8 103.4 2,! 104,1 2.[5 J03.3 2.8 103,8 3,0 104,0 3.3 ~05.0 3.5 108.5 3,7 107,0 3.6 108.9 3,8 108.2 4,2 108,0 4.6 108,6 4.9 109.9 5,2 110,0 5.6 110, 1 8.0 109.3 6,4 109,5 6.5 108,4 6,9 107.8 7,3 108,0 7.6 1.07.7 8.0 107.7 8,3 I07,6 8.8 107.3 8,9 107.5 8,9 108,2 9.2 If)? .9 9,5 108.u 9,8 109, 1 10.2 109.1 10,3 109,8 10.8 112.3 11,6 112.8 12,4 113,2 13.8 113.9 14.2 113.8 14.9 114.4 15.5 114.7 16.0 115.7 16.fl 116.3 17.4 118.2 18,5 116,2 19.3 116,5 20.2 117.0 21.0 117,5 21.6 118.0 22,4 117,8 22.§ 117,2 22.9 117.4 23,2 118.1 23.6 117.8 23,9 116.6 24,0 119,4 THE FIRST POINT INFOI~TION: 828.00 .0 ,0 THE LAST POINT IIfFORE&TION; 3508.00 24.0 119,4 FINAL MAST-~ST DRIFT FINAL NORTH-SOUTH DRIFT FINAL DRIFT DISTANCE FINAL DRIer DIRECTION ~.00 727.99 777,97 827,95 877.94 927,92 9??.89 1027.85 1077.80 1127.74 1177.66 1227.57 1277,47 1327,37 1377,27 1427.15 1477,01 1526,83 1576.64 1826.43 1676.17 1725.§8 1775,58 1825,22 1874.83 1924.41 1973,94 2023.44 2072,80 2122,27 2171.87 2221.05 ~270,39 2319.69 2388.93 2418.12 2467.28 2516,32 2565.22 2613.97 2862,55 2710.94 2759,19 2807.33 2855.29 2903.09 2950,66 2997.97 3045.01 3091.82 3136,39 3i84,77 3230.88 3278,99 3323.00 3368.88 3414,65 3440.23 628,00 3440,23 4bU,TZ E 198.09 S 495.08 FT S 68,41E N-S ,OON .55S .38S .17S .tBS 20S 29S 41S 48$ 54S 59S 84S .95S .91S ,96S 1.08S 1.23S 1,385 1.47S 1.60S 1,?IS 1.83S 1.85S 1,82S 1.92S 2.00S 2,07S 2.132 2.25S 2,32S 2.37S ~.bTS 2.?09 2.885 2.98S 3.31S 3,75S 4.04S 4 43S 4 75S 5 13S 5 43$ 5 74S 8 20S 0.46S 6.82S 7.20S ?.63S 8.08S 8.49S 8.75S 8.919 8.88S 9,13S 9.31S 9.45$ 5.50S · OON 5,50S .OOE .04E .82E I,OOE 1,16E 1.26E 1,41E 1.67E 1.94E 2,23E 2.46E 2,62E 2.87E 3.01E 3.01E 3,00E 3,30E 3.64E 3.89E 4,10E 4.39E 4.74E 5,09E 5.33B 5.52E 5.88E 8.21E 6,48E 6.72E 7. OBE 7.46E 7,38E 7.45E 7,?IE 7.90E 8.17E 8,48E 8.51E 8,97E 9,62E 10.20E 10.85E 11.46E 11.93E 12,25E 12.?OE 13.14E 13.81E 14.50E 15.12E 15.60E ~6.09E 16,53E l?.14E 17.20E 17.30E 17.68E 17.77E 9,98E ,ODE 9,98E , OOY · 55L .93S 1. 1. 285 1. 489 J. 77S 2. 2.66S 3 20S 3 782 4 47S 5 31S 6 28S 7 165 8.12S 9,20S 10.43S 11,80S 13.28S 14 16 59S 18 42S 20 26S 22 09S 24 OIS 26 OOS 28 08S 30, 21S 32 46S 34,785 37.15S 39,5OS 42, l OS 44.87S 47.75S 5O ?OS 54 O1S 57 7OS 61 BOS 65 23S ?0 98S 76 lis 81 54S 87 2OS 93.45S 99.94S 106.76S 113 96S 121 69S 129 68S 138 17S 1,t.6 92S 155 83S 164 699 t73 82S 183 14S 192 fi~S 198 09S , OON 198.09S .OOE .04E .85E 1.95E 3.11E 4.36E 5.78E 7.44E 9.39E ll,61E 14 07E 16 69E 19 66E 22 58g 25 59E 28 60E 31 8gE 35 94E 39 43E 43 53E 47 92E 52 66E 57 7bE 63.08E 68 74 48E 80 70E 87 17E 93 90E iO0 98E 108,43E ll5.?OE 1~3.24E 147.02E 165.48E 183.99E 172,97E 182,58E 192,79E 215.10E 227,04E 239.2~ 251.99E 265.13E 278.94E 293,45E 308.56E 324,16~ 34O.25E 356,78E 3?3 928 391 lie 408 41E 425 97E 443 74E 453 72E , OOE 4~ u3. '?2E 7,5 6O 80 100 - 120 - 140- 160- 1 BO 200 - S 000 75 000 150 t 22,.5 5OO 3000 37.'.5 450 52b 600 675 P LAN VIEW WELLBORE COURSE ~EASURED DEPTH TIE-IN WELLHEAD POSITION FINAL EAST-WEST DRIFT FINAL NORTtt-SOUTH DRIFf FINAL DRIFT DISIANCE AINAL DRIFT DIRECTION DRIFT UNI1S DEPTH UNITS 455.72 Fl' EAST' 198.09 FT SOUTH 495,0§ fl S 66.41E FEET FEET 5 0'0' ,! 400 30O I t00 tO0 .... I 1 ............... ' ......... i 400 500 1000 000 3000 SIDE VIEW FROM AZIMUTH 0 ,,./"": WELLBORE COURSE + : I~EASURED DEP1H lIE-IN ~: V~ELLHEAD POSITION MAX. DRIFT NgOE MAX. DRIFT SgOW B0710~ TVD THIS DRIFT UNITS OEPTH UNITS INT£RVAL 4~5.72 FT .02 FT 3440,23 f'T FEEl FEET 180 200~ 150 100 ~0 1000 O0 t 0 20O 3000 SIDE VIEW FROM AZIMUTH go ,,/"": WELLBORE COURSE + : MEASURED DEPTH TIE-IN ~: WELLHEAD POSITION ~AX. DRtF1 S E WAX. DRIFT N E BOTTOM TVD THIS DRIFT UNITS DEPTH UNITS iNTERVAL 198.09 Fl .00 FT 3440.25 FT FEE[ FEET 50 i O0 15O 2OO 250 300 350 4OO 450 50O '~ i 1000 2O00 5000 DEPTH WELLBORE COURSE ~EASURED DEPTH TIE-tN WELLHEAD POSITION VS. DRIFT ~AX. DRIFT FRO~ WELLHEAD BO}TO~ ~VD ldlS 1141ERVAL DRIFT UNil'5 DEPTH UNITS 495.08 FT 3,~0.23 FT FEET FEET .-- STATE OF .... ' ALASKA Ol,.. ,ND GAS CONSERVATION ,.,.-.~,,,,MISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdowm Re-enter suspend';'d well: Alter ~a~ing: Repai~¢l: Plugging: Time extension; Stimulate: Charlge approved p~;ogram: Pull {u'"~'~ing: Varlan'--'-~: XX Pedorate~ O~er: 2, Name of Operator 5. T~e of well; 6, Datum elevation (DF or KB) Ocean E~ergy, Inc, Development; X KB; 280' . .... feet 3, Addr~s Exploratow: ?, Unit or Prope~ name Stra~igraphic; 1670 Broadway, Suite 2800, Denver, CO. 80202-4826 So.Ice: Pioneer Unit 1702 4, Location of well at sudace 8. Well number ~00' ~L & ~0' FSL Sec. 14-T17N-R~ 14CC At top of produdive intewal 9. Peri( number 99-6~ At effem~e depth 500' ~L & 820' FSL Sec. 14-T17N-R~ '10.'AP~ ~u'mber 50- ~09-20016 A~ total dept~ 500' ~L & 820' F$L Sec, 14-TI?N-R2W 11. Field/P¢o~ Pioneer Unit~yo~ek lZ, Presem well condition summaw To~I depth: measured feet Plugs (measured) t~e vedi~l fee[ Effadjw depth: m~asu~d feet Junk (measured) true vedi~l feet Casing Length 81~e Oe~ented Measured depth T~e ve~lcal depth Strumuml Conductor Inte~diate PrecluSion Perforatlon de~th: measure~ ORIGINAL Tubing (she, grade, and measured depth) .';.~2';~<a oil & 0;3 cons. Commissiorl Anchorage Packem and SSSV (~pe and measured depth) 13. A~aehemen~ Description summa~ of proposal: X D~{all~'~"~eratl~ns pr0gra~ 14. Eslima~d dale fo~ commencing epera~en 1~. Status of well ¢la~[fl~lon ~s'. s~udded 8/28/99 at 2:00AM, 16. If proposal well verbally apffmved: Off: Gas; X Suspended; ~O~ Name ofa~rover BlairWondzell 8/26/9g Date approved Se~[~: 17. I hereby ~I~ that the foregoing is line and corm~ [o th~ bsst of my knowledge. // 8i~ned:~~ ~ /¢ ~itle Regulatow Cao~inator Date: 8/30/99 Candlllo.s ~ ~¢¢'~o~1: N;II~ ~mmlssion so mp~sentative may wilness IApPr°val No. Plug int~rl~ BOP Tes~ Lo~t[on clearance .... Mechanical lnt~ri~ Tes~ Subsequent fo~ required 1~ O~IGINAL SIGNED BY Apprewd by o~er of the Comm~sioner RQ~ N. Chds~ns~ Commissioner . Form lO-40:~ Rev 06/1 $18~ SUBMIT IN TRIPLICATE U~LHH LHLR~Y KLUUUK~Lb August 30, 1999 Pioneer Unit 1702 #140C Section 14-T17N-R2W Matanuska-Susitna Borough Diverter Variance Request At this time OEI is requesting a vadance on the stipulation that a 13 3-/8" diverter be used an the #14CC well while the well is spudded and the conductor pipe is set. Set the surface conductor to 35' and then use the normal set-up for the remainder of the well, with out a diverter on the stack. VVhen OEI was ddlling the Pioneer Unit 1702 #15DA VVIW, located (+-) 1300 feet to the we~t of the #14CC location, no shallow gas zones were present in the upper zones where the conductor pipe was set. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Robert Christenson Chairman DATE: THRU: Blair Wondzell, ~ FILE NO: P. I. Supervisor FROM: John H Spauiding~__~/~ SUBJECT: Petroleum Inspectgt August 30, 1999 CH&P rig 19.doc BOPE Test CH&P rig 19 Pioneer Unit well 14_CC Ocean Energy PTD 99-65 Auoust 30, 1999: I traveled to the Ocean Energy location near Big Lake, -- Alaska to witness the BOP test on CH&P rig 19. The AOGCC BOPE Test report is attached for reference. As noted on the test report, no failures were observed. Although we did have some operational challenges getting all of the appropriate hoses and line hooked up correctly and the connections tightened. The test went quite well considering most of the people on the rig have never worked on a rig this small. On Sept. 2 & 3 of 1999 I again traveled to the Big Lake area to inspect and watch an abbreviated BOP test on CH&P rig 23. The rig was taking the place of the CH&P rig 19, ali the BOPE was being left in place from rig19. The testing went well and the rig appeared to be in pretty fair shape. SUMMARY: i witnessed the BOPE test on CH&P rig 19; 12 valves, no failures, 0 failure rate Attachment: CH&P rig 19.xis STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Ddg Contractor: Operator: Well Name: Casing Size: Test: Initial . X Workover: CH&P Rig No. 19 PTD# Unocal / Ocean Ener~ly Rep.: 14-CC Rig Rep.: Set @ Location: Sec. Weekly X Other 99-65 DATE: 8/30/99 Rig Ph.# 373-1037 Dennis Ackerman Brian Busby 14 T. 17N R. 2W Meridian Seward MISC. INSPECTIONS: Location Gen.: ok Housekeeping: ok (Gen) PTD On Location ok Standing Order Posted ok Well Sign ok Dd. Rig ok Hazard Sec. ok BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. P/F I 250/2,500 P 250/2, 500 P I 250/2, 500 P I 250/2, 500 P I 250/2, 500 P I 250/2, 500 P I 250/2, 500 P FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure P/F 1 250/2,500 P 1 250/2, 500 P 1 250/2, 500 P I 250/2,500 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure P/F 5 250/2,500 P 13 25072, 500 P 2 P na Fun~ioned Fun~ioned ACCUMULATOR SYSTEM: System Pressure 1,300 I P Pressure After Closure 1,200 P MUD SYSTEM: Visual Alarm 200 psi Attained After Closure minutes 9 Tdp Tank ok ok System Pressure Attained minutes 25 Pit Level Indicators ok ok Blind Switch Covers: Master: Remote: Flow Indicator ok ok Nitgn. Btl's: 3 ~2300av~ PS! Meth Gas Detector ok ok Psig. H2S Gas Detector ok ok Number of Failures: 0 ,Test Time: 5.5 Hours. Number of valves tested 12 Repair or Replacement of Failed Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Znspector North Slope Pager No. 65g-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Distribution: odg-Well File c - Open/Rig c - Database c - Trip Rpt File c- Inspector STATE WTFNESS REQUIRED? YES X NO 24 HOUR NOTICE GZVEN YEs X NO Waived By: Witnessed By: John H. Spaulding FI-021L (Rev. 12/94) CH&P dg 19 Pioneer Unit 1702 #14CC well, ...7N-R2~.- Matanuska-Susitna Borough. Subject: Date: From: Organization: To: CC: Re: Pioneer Unit 1702 #14CC well, 500' FWL & 820' FSL Sec 14-T17N-R2W, Matanuska-Susitna Borough. Thu, 26 Aug 1999 15:40:11 -0800 Blair Wondzell <blair_wondzell~admin.state.ak.us> State of Alaska, Dept of Admin, Oil & Gas "Webb, S. (Scott)" <Scott.Webb~OceanEnergy.com>, Camille Oechsli <cammy oechsli~admin.state.ak.us> "Wilson, Chuck" <Chuck. Wilson~OceanEnergy.com>, Robert Crandall <bob_crandall~admin.state.ak.us>, Robert Christenson <robert_christenson~admin.state.ak.us> Scott, Bob Crandall and I evaluated this request and discussed it with commissioners Christenson and Oechsli. We have determined that we can give verbal approval to the waiver of the diverter on Pioneer Unit well 1702-14CC pending formal approval via a 10-403. At your earliest convience, please prepare and submitt a 10-403 for formal approval. Blair Wondzell 8/26/99 "Webb, S. (Scott)" wrote: Mr. Wondzell, Ocean Energy, Inc. (OEI) is planning on spudding the subject well on either Friday the 27th of August or Saturday the 28th of August. At this time OEI is requesting a variance on the stipulation that a 13 348" diverter be used on the #14CC well while the well is spudded and the conductor pipe is set. Instead, we would just set the surface conductor to 35' and then use the normal set-up for the remainder of the well, with out a diverter on the stack. When OEI was drilling the Pioneer Unit 1702 #15DA WIW, located (+-) 1300 feet to the west of the #14CC location, no shallow gas zones were present in the upper zones where the conductor pipe was set. I can be reached at the above listed E-mail address or by my direct telephone line at (303) 308-8863. Thank you for your time and help in this matter. Scott Webb 1 of 1 8/26/99 3:40 PM Plo;~eer Unit 1702 #14CC well, 500'...N-R2gL.-~Matanuska-Susitna Borough. - . Subject: Pioneer Unit 1702 #14CC well, 500' FWL & 820' FSL Sec 14-T17N-R2W, Matanuska-Susitna Borough. Date: Thu, 26 Aug 1999 13:01:18 -0500 From: "Webb, S. (Scott)" <Scott. Webb~OceanEnergy.com> To: "'blair wondzell~admin, state, ak.us'" <blair_wondzell~admin. state, ak. us> CC: "Wilson, Chuck" <Chuck. Wilson~OceanEnergy.com> Mr. Wondzell, Ocean Energy, Inc. (OEI) is planning on spudding the subject well on either Friday the 27th of August or Saturday the 28th of August. At this time OEI is requesting a variance on the stipulation that a 13 3-/8" diverter be used on the #14CC well while the well is spudded and the conductor pipe is set. Instead, we would just set the surface conductor to 35' and then use the normal set-up for the remainder of the well, with out a diverter on the stack. When OEI was drilling the Pioneer Unit 1702 #15DA WIW, located (+-) 1300 feet to the west of the #14CC location, no shallow gas zones were present in the upper zones where the conductor pipe was set. I can be reached at the above listed E-mail address or by my direct telephone line at (303) 308-8863. Thank you for your time and help in this matter. Scott Webb 1 of 1 8/26/99 2:51 PM TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 August4. 1999 Scott Webb Regulatory. Coordinator Ocean Energy Resources, Inc. 1670 Broadway. Suite 2800 Denver. CO 80202-4826 Pioneer Unit 1702 14CC Ocean Energy Resources. Inc. Permit No: 99-65 Sur Loc: 500'FWL. 820'FSL. Sec. 14. T17N, R2W, SM Btmhole Loc. 500'FWL. 820'FSL. Sec. 14, T17N, R2W. SM Dear Mr. Webb: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required bv law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Your request for diverter waiver is approved. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of thc Commission to witness a test of BOPE installed prior to drilling new hole. Notice mav be given bv contacting the Commission at 279-1433. Since ' Robert N. Christenson. P. E. Chairman BY ORDER OF THE COMMISSION dlf/Enclosures CC: Department of Fish & Game. Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA O!' ,ND GAS CONSERVATION 'MMISSION PERMIT TO DRILL I a. Type of work Drill: X Redrill: 1 b. Type of well Exploratory: X Stratigraphic Test: Development Oil: Re-Entry: Deepen: Service: Developement Gas: X Single Zone: Multiple Zone: 2. Name of Operator 10. Field and Pool Ocean Energy, Resources, Inc. 3. Address 1670 Broadway, Suite 2800, Denver, CO 80202-4826 4. Location of well at surface 500' FWL & 820' FSL At top of productive interval 500' FWL & 820' FSL At total depth 500' FWL & 820' FSL Sec. 14-T17N-R2.W 12. Distance to nearest property line 5C0' feet 13. Distance to nearest well NA feet 16. To be completed for deviated wells Kickoff depth: feet 18. Casing program size Hole I Casing Maximum hole angle: 5. Datum Elevation (DF or KB) GL:269' KB: 280 feet 6. Property Designation ADL-374117 7. Unit or property Name Pioneer Unit I'/O ~-- 8. Well number · -'F,T'~ 14CC 9. Approximate spud date Upon Approval 14. Number of acres in property 2721.06 Pioneer Unit 11. Type Bond (see 20 AAC 25.025) Number JZ-8072 Amount $200,000.00 15. Proposed depth (MD and '[VD) 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) 4,100' feet Maximum surface 1410 psig At total depth (TVD) 1500 psig Settini Depth Specifications Top Bottom WeightIGradeI Couplingl Length MD I TVO MD I TV. 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 I I I , ;sSxx 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 Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured aepth True vertical depth measured ': .;" it ~; ''''": ., ,,':j:f'~- true venial ~S~ v A~Cb0f~ 20. AEachments: Filing fee: ~ Prope~ Plat: ~ BOP Sketch: XX DiveKer Sketch: NA Drilling program: Drilling fluid program: ~ Time vs. depth plot: Refra~ion analysis: Seabed repo~: 20 ~C 25.050 requirements: 21. I herby ~Ki~ that the foregoing is tree and ~rrect to the best of my knowledge: Commission Use Only Permit Number I APl number I Approv. a. date ~,¢ I See cover letter ~;1~;t~, ~',~- 50- (:~ ~ -- ~-. <3~ ~3 / ~' ~ '" 5" for other requirements Conditions of approval Samples required: [ ] Yes '~ No Mud log required: [ ] Yes J~ No Hydrogen sulfide measures [ ] Yes ~No Directional survey required [ ] Yes J~J No Required working pressure forSOPE [ ]2M; [ ]3M; [ ]5M; [ ]10M; [ ]15M ~ ~p~ Other: ORIGINAL SIGNED 8Y by order of Approved by Robert N. Christen~op Commissioner the Commission Form 10-401 Rev. 12-1-85 20 AAC 25.005 6/28/99 Date: Submit in triplicate Pioneer Unit #'~. J2-14CC Proposed Completion SW SW Section 14-T17N-R2W Matanuska-Susitna Borough, AK GL: 269' 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 1,500' and 4,000' (estimated). 7) TD: 4,100' 6 7 DRILLING PROGNOSIS PIONEER UNIT "TIGHT HOLE" WELL: #1702-14CC FIELD: Pioneer Unit DIRECTIONS to LOCATION: From Anchorage, AK: SURFACE LOCATION: SW SW Section 14, T17N, R2W, Matanuska-Susitna Borough, Alaska ELEVATIONS: GL: 269' & KB: 280' ESTIMATED TD: 4,100' MD PRIMARY OBJECTIVE: Tyonek Formation DRILLING CONTRACTOR: CH&P Drilling Company ON-SITE CONSULTANT: Dennis Ackerman ON-SITE GEOLOGIST: Noel Waechter 1999 PIONEER UNIT DRILLING PIONEER PROSPECT #1702-14CC Section 14, T17N-R2W Matanuska-Susitna Borough, Alaska GENERAL 1.) Ocean Energy, Inc has approved drilling and completion of a test of the Tyonek formation in the Pioneer Prospect of Alaska. The well name, AFE number and AFE cost are listed below. Well Name AFE # # 1702-14CC DND971 AFE'd Costs Dryhole Costs: Completion Costs: Total D&C Costs: $354,325. $418,785. $773,110. 2.) The #1702-14CC well is on state 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. Morning reports shall be faxed to both the Denver and Gillette offices by 7:00 am Rocky Mountain Time every moming. See phone list for fax numbers. Daily report will include: Depth (TVD & MD); Operations; Formation; Bit No. (size, type, and grade when pulled); Weight on Bit; Rotary Table RPM; Pump Pressure; Annular Velocities around DP & DC's; HHP at bit; Each DC ID & OD; BHA with Lengths and ID's & OD's; Surveys (azimuth, bearing X-Y coordinates, total displacement); Mud Properties (weight, viscosity, water loss, filter cake, % solids, % LCM, pH, chlorides, gel strengths, PV, YP, Ca, materials used, daily and total mud costs) 4.) All costs are to be carded on the daily drilling report. A 10% contingency shall be added to all items except for footage, daywork and casing costs to cover taxes and any missed costs. 5.) We will be drilling on state land. OEI currently has a good working relationship with the state, therefore, every effort to keep trash cleaned up, traffic and road damage to a minimum and run a "clean" operation should be made during drilling and completion of this well. PIONEER #1702-14CC 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 f-t2) 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 ting, first four collars, and every other collar for eight collars thereafter. Thread lock guide shoe, shoe joint and float collar. Depth Interval Casing Burst/SF Collapse/SF 0'- 700' 9-5/8" 36#/ftJ-55 STC 3,520psi/8.80 2,020psi/6.313 Tension/SF 394 Mlbs/15.63 (J) PIONEER #1702-14CC MATANUSKA-SUSITNA BOROUGH, AK SURFACE HOLE: surface to700' (continuea) 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 ,,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 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 #1702-14CC MATANUSKA-SUSITNA BOROUGH, AK PRODUCTIONHOLE: 700' TO 4,100' At'rer 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 o Always slow trip speed down to no more than 60 seconds per stand below 2500 f~ to prevent formation breakdown from hole surging. 4. If possible, Always wash and ream the last 60' of hole drilled before making a connection. 5. Keep hole full at all times! 6. Absolutely, No Smoking, Alcohol or Firearms on Location. PR OD UCTION HOLE MUD PROGRAM: MI (MI Bar, Soda Ash, Polypac, Soltex, Desco CF, Bicarb, Caustic Soda, PolyPlus RD, and Tannathin) The production hole will be drilled with as few chemical additions as possible. Well conditions will dictate fluid decisions. Preparations and materials will be available to weight up, viscosify, or disperse this system as hole conditions warrant. Use surface mud to drill 9-5/8" float collar, cement and shoe, then treat the fluid for cement contamination. Continue drilling ahead and allow weight to increase from drill solids to 9.5 ppg. Use dispersants as necessary to keep viscosity under 75 sec/qt. Weight up system if necessary to control pressurized inflow. Use centrifuge only as necessary to control viscosity and yield point. Lower fluid loss with Polypac only if directed by the 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 ~) Solids (lgs) Build production hole mud from surface hole mud 10.0 to 11.5 75 or less 10 or less N/C 30to 35 20 to 25 13 to 24% PIONEER #1702-14CC MATANUSKA-SUSITNA BOROUGH, AK PRODUCTION HOLE: 700' TO 4, !00' (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 cut through the Tyonek formation on the second or third well across the Tyonek P Coal or the Tyonek BLT Coal to allow determination of reservoir properties. Geology: Formation #1702-14CC GL = 269' KB = 280' Depth / SS Datum Glacial Gravel Surface/(280') Tyonek 510'/(-230') Tyonek B Coal 1,030'/(-750') Tyonek B Sand 1,300'/(-1,020') Tyonek C Sand 1,765'/(-1,485') Tyonek C Coal 2,250'/(-1,970') Tyonek P Coal 3,175'/(-2,895') Tyonek BLT Sand 3,420'/(-3,140') Tyonek BLT Coal 3,600'/(-3,320') Estimated TD 4,100'/(-3,820') 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 TensionfSF 287 Mlbs/3.75(J) PIONEER #1702-14CC MATANUSKA-SUSITNA BOROUGH, AK PROD UCTION HOLE: 700' to 4,1 oo' (Conanued) 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 cement to a planned TOC at surface. Thread lock the stage collars onto the next joint of casing above. Cement Program -20 bbls Mud Clean II -lst Stage: 221 sxs "G" Cmt + 0.3% CD32, 0.4% FL33, 1 gal/100 sxs FP6L, & 0.3% SMS -Drop plug, displace with fresh water and bump plug to 1,000 psi -Drop ball to open stage tool located at 2,700' and circulate bottoms up with fresh water -Allow a total of 4hrs WOC after 1 ~ stage before pumping 2~a 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 4hfs WOC after 2nd stage before pumping 3rd stage -10 bbls Mud Clean II -3rd Stage: 113 sxs "G" Cmt + 1.00% CaC12, 0.4% CD32, 1 gal/100 sxs FP6L, 2.0% SMS -Drop plug, displace with fresh water, bump plug and close stage tool at 1,400' -Bleed pressure off well and wait on cement Cement Properties Slurry Weight (g/Gall) Slurry Yield (Cubic-FtYSx) 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, 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 & set slips. ND BOPE & Make cut on 7" casing. Nipple up tubing head. PIONEER #1702-14CC 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 = $10,405.83 Plus taxes and shipping Joe Brewer - Denver, CO Ken Kubiak or Pete Thoeni- Anchorage, AK (303) 861 - 1850 (907) 562 - 2332 Fax: (907) 562 - 3880 Mud Company: MI Drilling Fluids John Couch- Denver, CO (303) 623 - 0911 Deen Bryan- Anchorage, AK (907) 274- 5564 PIONEER #1702-14CC 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 #1702-14CC 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: _ l0 BLOWOUT PRE~,:NTER SYSTEM Pioneer Unit Ocean Energy, Inc. 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 Fill Line Annular I I [~ R-Pipe Rams ) I I I I I I R-Blind Rams I I ! spoo, ! I KillLinesl 3000 PSI WP Flow Line 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 Diverte~4Rating: Active 3,000 PSI Static 5,000 PSI CH&P RIG #19 Hydraulic Oil - 100 gal. Motor Oil -200 gal. Gear Oil - 100 gal. 4700 gal. Diesel fuel! 285' bbl. Fresh Water 150 bbl. Light Plant Dog House Brine Tank ,. ,,' ~! Unit Brine for Hydromatic - 220 gal. Mud Pump Hydraulic Oil - 260 gal. Diesel Fuel 199 gal. Mud Pit 300 bbl. Rig Floor i/ Reserve Pit Pipe Racks Cat Walk Guylines - 60' back / 45' out from center /lines - 60' front / 60' out from center 35 feet from center of well to reserve pit bi LLI Found survey monument II I PIONEER 1 4CC ~RID N: 2761957.075 JGRID E: 570327;276 ,, ,,,-, E',.,,,:~:~:..,. /ILATITUDE: 61'53 51.801 Proposed Surfo~,= ~,,,,~,==/ ~ONGITUDE: 149'55'48.117" ~ ASP ZONE 4 NAD27 I ._~,/ [ GL : 269 ~oo' I -~ Access ] Rood sw ~/4 sw ~/~ SECTION 1 4 T17N, R2W, S.M., AK South Line Section 14 Found survey monument 820' SCALE 1"= 200' 1) Bosis of Horizontol Coordinetes Store of Alosko DOT&PF Georeferencing Project (;PS Control Stotions BigL & 040. OCEAN ENERGY, INC. PIONEER UNIT If1702-14C0 SURFACE LOCATION 500' FWL end 820' FSL Surveyed by:, 993060 Job No: ....... Prepored For: Oceon Energy Inc. 1670 Broodwoy Suite 2800 Denver, CO 80202 McL~Av [nNgiEn e 2,0S uNr very cUr sL?dNp fGo n nerG?OUP P.O. Box 468 Soldotno, AK 99669 99-20 June 19, 1999 Field Book No. Date: JUL D( '~ Db;d~Hl'l ULbHH EHLNbY F.i/~I FAX COVER SHEET Ocean Ener~o-y Resources, Inc. 1670 Broa&v~ - Denver, Colorado Telephone: (303) 308-8.500 DENVER OFFICE NOR TH ,4MER IC4 - Oh~2HORE OERI Fav ~ r303) 308-,75 ~ 0 OER[ Operation ~ Fc~x ~ ;303) ?ages taxed: ......... ~! ....... : ...... (Includes cover sl~eer) ..~.o7 ...... ~.~..m.~,~ ........... ,~ ......... ;~V_~,..L ........ ~~.g ...... v.~.? ........................ '... ..................... , ................... ' ........................ T'I' - ' ........ following t~i~p~on~ number (303) JUL July 7, 1999 Alaska Oil and (]as Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: Drilling and Recompletion Plans Pioneer Unit · Matanuska-Susitna Borough, AK Dear Mr. BlsJx Wondzell: . Thank you for your assistance on completing the AOGCC APD requirements for the upcoming Pioneer Unit project. Ocean Energy Resources, Inc plans to start work on the Pioneer Unit:project with spud of the first well tentatively planned for the week of/ruly 19, 1999. Attached are copies of the drilling prognosis for the three planned new wells (lwo 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 dewatemd solids from the drilling fluid in their Central Landfill after pre-disposal testing has determined that the solids are free of hazardous contaminates.. Remaining liquids from the drilling fluid ~11 be disposed by injection into the proposed water disposal well, #1702-i 5AD, which is the first well planned for drilling in the project. No drillhig 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 ofopenhole 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 will 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. Pleas~ 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. W~ton Rocky Mountain Area Production Man~ O~ean Erler~y FI~K~#r~ Ino. Amoco1~u~l~ 1670~roadway~ Sutt~2800 Denver, Colorado 80202 (303) 308-8,500 Fax: 11303) ;50~-$510 I, . ATTACHMENT #1 Ocean Energy Resources, Inc requests a waiver to not utiliz~ a divertcr during drilling of the 12-1/4" Surface Hole due to no shallow gas down to 700' below surface, Ocean Energy Resources, Inc will perform an 11.5 ppg FIT by drilling 10 feet b~low the 9~.5/8" Surface Casing Shoe, then pumping to an equivalent mud weight test to 11.5 ppg at the surface casing shoe. WELL PERMIT CHECKLIST fIELD & POOL _'~ / 0 ,..~ COMPANY ADMINISTRATION APPR ENGINEERING INIT CLASS /--' ~ ~-, T / '-- 1. Permit fee attached ........... : ........... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included...,,'t/', .,~ ......... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... 14. Conductorstdng 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 stdng to surf csg ........ 18. CMT will cover all known productive hodzons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. WELL NAME/~d~ ~ _/z;~, <~ ,~. PROGRAM: exp dev ,"X redrll GEOL AREA ~g~.,2_._~.) UNIT# serv wellbore seg ann. disposal para req ON/OFF SHORE c~ ~J DATE 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to "~ 5'~O 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 ................. N N Y® GEOLOGY Permit can be issued w/o hydrogen sulfide measures ..... yY N / Data presented on potential overpressure zones ....... Seismic analysis of shallow gas zones ............. y~NN Seabed condition survey (if off-shore) ............. Contact name/phone for weekly progress reports [exploratoryo,~ly] Y N 30. 31. 32. 34. APPR ANNULAR DISPOSAL APPR DATE 35. With proper cementing records, this plan (a) will contain waste in a ~~~iving zone;~.>_..~.'-'. . . Y N (B) will not contaminat~shwater; or cauls, e-drilling waste... Y N to surface; (C) will noh~'~r mecha~grity of the well used for disposal; Y N (D) will/rj.ot"damage producing formation or impair recovery from a Y N peril; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N ENGINEERING: UlC/Anr~~.. COMMISSION: BEW,~ -.-?.~,, _ DWJ JDH ~ RNC CO CC> 4"/z ~!,~ ~. Comments/Instructions: c:\msoffice\wordian\diana\checklist